FORM 10-K
SECURITIES AND EXCHANGE COMMISSION
Washington, D. C. 20549
[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934 [Fee Required]
For the fiscal year ended December 31, 1995
Commission file number 1-40
PACIFIC ENTERPRISES
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(Exact name of Registrant as specified in its charter)
California 95-0743670
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(State of incorporation) (IRS Employer Identification No.)
555 West Fifth Street, Suite 2900, Los Angeles, California 90013-1011
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(Address of principal executive offices) (Zip Code)
(213) 895-5000
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(Registrant's telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
Name of each exchange
Title of each class on which registered
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Common Stock and Associated New York Stock Exchange
Common Stock Purchase Rights Pacific Stock Exchange
Preferred Stock
$4.75 dividend
$4.50 dividend American Stock Exchange
$4.40 dividend Pacific Stock Exchange
$4.36 dividend
Securities registered pursuant to Section 12(g) of the Act: None
Indicate by check mark whether the Registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act
of 1934 during the preceding 12 months and (2) has been subject to such
filing requirements for the past 90 days.
Yes X No
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Indicate by check mark if disclosure of delinquent filers pursuant to Item 405
of Regulation S-K is not contained herein, and will not be contained, to the
best of Registrant's knowledge, in definitive proxy or information statements
incorporated by reference in Part III of this Form 10-K or any amendment to this
Form 10-K. [X]
The aggregate market value of Registrant's voting stock (Common Stock and Voting
Preferred Stock) held by non-affiliates at March 15, 1996, was approximately
$2.3 billion. This amount excludes the market value of 97,891 shares of Common
Stock held by Registrant's directors and executive officers.
Registrant's Common Stock outstanding at March 15, 1996, numbered 84,809,613
shares.
DOCUMENTS INCORPORATED BY REFERENCE
Certain information in this Annual Report is incorporated by reference to
information contained or to be contained in other documents filed or to be filed
by Registrant with the Securities and Exchange Commission. The following table
identifies the information so incorporated in each Part of this Annual Report on
Form 10-K and the document in which it is or will be contained.
Information Incorporated
by Reference and Document
Annual Report in Which Information is or
On Form 10-K will be Contained
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Part II Information contained under the captions
Financial Review -- Management's
Discussion and Analysis", "Quarterly
Financial Data", "Range of Market
Prices of Capital Stock" and "Selected
Financial Data and Comparative
Statistics 1985-1995", in Registrant's
1995 Annual Report to Shareholders.
Part III Information contained under the
captions "Election of Directors", "Share
Ownership of Directors and Executive
Officers" and "Executive
Compensation" in Registrant's Proxy
Statement for its Annual Meeting of
Shareholders scheduled to be held on
May 9, 1996.
TABLE OF CONTENTS
Page
PART I
Item 1. Business......................................................5
Pacific Enterprises...........................................5
Southern California Gas Company...............................5
Operating Statistics.....................................6
Service Area.............................................7
Utility Services.........................................8
Demand for Gas...........................................8
Competition..............................................9
Supplies of Gas.........................................10
Rates and Regulation....................................12
Properties..............................................13
Energy Management Services...................................13
Pacific Enterprises International............................13
Environmental Matters........................................14
Employees....................................................14
Management...................................................15
Item 2. Properties...................................................16
Item 3. Legal Proceedings............................................16
Item 4. Submission of Matters to a Vote of Security Holders..........16
PART II
Item 5. Market for Registrant's Common Equity
and Related Stockholder Matters..............................17
Item 6. Selected Financial Data......................................17
Item 7. Management's Discussion and Analysis of Financial
Condition and Results of Operations..........................17
Item 8. Financial Statements and Supplementary Data..................17
Item 9. Changes in and Disagreements with Accountants on
Accounting and Financial Disclosure..........................17
PART III
Item 10. Directors and Executive Officers of the Registrant...........18
Item 11. Executive Compensation.......................................18
Item 12. Security Ownership of Certain Beneficial Owners
and Management...............................................18
Item 13. Certain Relationships and Related Transactions...............18
PART IV
Item 14. Exhibits, Financial Statement Schedules,
and Reports on Form 8-K......................................19
PART I
ITEM 1. BUSINESS
PACIFIC ENTERPRISES
Pacific Enterprises is a Los Angeles-based utility holding company
engaged in supplying natural gas throughout most of southern and part of central
California. These operations are conducted through Southern California Gas
Company, the nation's largest natural gas distribution utility. Through other
subsidiaries, Pacific Enterprises is also engaged in interstate and offshore
natural gas transmission to serve its utility operations, in alternate energy
development and centralized heating and cooling for large building complexes.
In 1995, Pacific Enterprises completed a realignment into five
business units which establishes a more flexible design to allow a more rapid
response to competitive forces. Pacific Enterprises was incorporated in
California in 1907 as the successor to a corporation organized in 1886. Its
principal executive offices are located at 555 West Fifth Street, Los Angeles,
California 90013-1011 and its telephone number is (213) 895-5000.
SOUTHERN CALIFORNIA GAS COMPANY
Pacific Enterprises' principal subsidiary is Southern California Gas
Company ("SoCalGas"), a public utility owning and operating a natural gas
distribution, transmission and storage system that supplies natural gas in 535
cities and communities throughout most of southern California and part of
central California. SoCalGas is the nation's largest natural gas distribution
utility, providing gas service to approximately 17 million residential,
commercial, industrial, utility electric generation and wholesale customers
through approximately 4.7 million meters in a 23,000-square mile service area.
SoCalGas is subject to regulation by the California Public Utilities
Commission ("CPUC") which, among other things, establishes the rates SoCalGas
may charge for gas service, including an authorized rate of return on
investment. Under current ratemaking policies, SoCalGas' future earnings and
cash flow will be determined primarily by the allowed rate of return on common
equity, changes to authorized rate base, noncore market pricing and the variance
in gas volumes delivered to these noncore customers versus CPUC-adopted forecast
deliveries and the ability of management to control expenses and investment in
line with the amounts authorized by the CPUC to be collected in rates. The
impact of any future regulatory restructuring (including the performance based
regulation ("PBR") proposal (See "Rates and Regulation")), increased
competitiveness in the industry (including the continuing threat of customers
bypassing SoCalGas' system and obtaining service directly from interstate
pipelines), and electric industry restructuring may also affect SoCalGas' future
performance.
For 1996, the CPUC has authorized SoCalGas to earn a rate of return on
rate base of 9.42 percent and 11.6 percent rate of return on common equity
compared to 9.67 percent and 12 percent, respectively, in 1995. Rate base
declined 3.4 percent in 1995. In 1996, rate base is expected to decline
slightly from the 1995 level. SoCalGas has achieved or exceeded its authorized
return on rate base for the last thirteen consecutive years.
OPERATING STATISTICS
The following table sets forth certain operating statistics of
SoCalGas from 1991 through 1995.
YEAR ENDED DECEMBER 31
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1995 1994 1993 1992 1991
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Gas Sales, Transportation & Exchange
Revenues (thousands of dollars):
Residential $1,553,491 $1,712,899 $1,652,562 $1,483,654 $1,673,837
Commercial/Industrial 751,409 798,180 853,579 836,672 977,065
Utility Electric Generation 104,486 118,353 147,208 194,639 148,573
Wholesale 62,256 98,354 116,737 128,881 144,779
Exchange 777 690 3,745 5,863 7,482
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Total in rates 2,472,419(1) 2,728,476(1) 2,773,831 2,649,709 2,951,736
Regulatory balancing accounts
and other (193,111) (141,952) 37,243 190,216 (21,430)
----------- ----------- ---------- ---------- ----------
Operating Revenue $2,279,308 $2,586,524 $2,811,074 $2,839,925 $2,930,306
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----------- ----------- ---------- ---------- ----------
Volumes (millions of cubic feet):
Residential 239,417 256,400 247,507 243,920 249,522
Commercial/Industrial 351,649 347,419 339,706 363,124 460,368
Utility Electric Generation 204,582 260,290 212,720 220,642 170,043
Wholesale 128,730 146,279 147,978 149,232 141,931
Exchange 12,735 10,002 16,969 23,888 25,604
----------- ---------- ---------- ---------- ---------
Total 937,113 1,020,390 964,880 1,000,806 1,047,468
----------- ---------- ---------- ---------- ----------
----------- ---------- ---------- ---------- ----------
Core 324,758 341,469 338,795 334,630 351,432
Noncore 612,355 678,921 626,085 666,176 696,036
----------- ---------- ---------- ---------- ---------
Total 937,113 1,020,390 964,880 1,000,806 1,047,468
----------- ---------- ---------- ---------- ---------
----------- ---------- ---------- ---------- ---------
Sales 337,952 362,624 352,052 355,177 411,414
Transportation 586,426 647,764 595,859 621,741 610,450
Exchange 12,735 10,002 16,969 23,888 25,604
----------- ---------- ---------- ---------- ---------
Total 937,113 1,020,390 964,880 1,000,806 1,047,468
----------- ------------ ------------ ---------- ---------
Revenues (per thousand cubic feet):
Residential $6.49 $6.68 $6.68 $6.08 $6.71
Commercial/Industrial $2.14 $2.30 $2.51 $2.30 $2.12
Utility Electric Generation $0.51 $0.45 $0.69 $0.88 $0.87
Wholesale $0.48 $0.67 $0.79 $0.86 $1.02
Exchange $0.06 $0.07 $0.22 $0.25 $0.29
Customers
Active Meters (at end of period):
Residential 4,526,150 4,483,324 4,459,250 4,445,500 4,429,896
Commercial 184,470 187,518 187,602 189,364 193,051
Industrial 22,976 23,505 23,924 24,419 25,642
Utility Electric Generation 8 8 8 8 8
Wholesale 3 3 3 2 2
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Total 4,733,607 4,694,358 4,670,787 4,659,293 4,648,599
----------- ----------- ----------- --------- ---------
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Residential Meter Usage (annual average):
Revenues (dollars) $345 $383 $371 $334 $380
Volumes (thousands of cubic feet) 53.2 57.4 55.6 55.0 56.6
System Usage (millions of cubic feet):
Average Daily Sendout 2,579 2,795 2,611 2,717 2,881
Peak Day Sendout 4,120 4,350 4,578 4,547 4,356
Sendout Capability (at end of period) 8,059 7,570 7,351 7,419 7,073
Degree Days (2):
Number 1,215 (3) 1,459 1,203 1,258 1,409
Average (20 Year) 1,380 1,418 1,430 1,458 1,474
Percent of Average 88.0% 102.9% 84.1% 86.3% 95.6%
Population of Service Area
estimated at year end) 17,260,000 17,070,000 15,600,000 15,600,000 15,600,000
(1) Beginning January 1, 1994, rates included the ratepayer's portion of the
Comprehensive Settlement (the amount included in rates for 1995 and 1994
was $84 million and $119 million, respectively.) (2) The number of degree
days for any period of time indicates whether the temperature is relatively
hot or cold. A degree day is recorded for each degree the average
temperature for any day falls below 65 degrees Fahrenheit. (3) Estimated
calendar degree days.
6
SERVICE AREA
SoCalGas distributes natural gas throughout a 23,000-square mile
service territory with a population of approximately 17 million people. As
indicated by the following map, its service territory includes most of
southern California and part of central California.
[MAP OF SOUTHERN CALIFORNIA GAS COMPANY SERVICE TERRITORY]
Natural gas service is also provided on a wholesale basis to the distribution
systems of the City of Long Beach, San Diego Gas & Electric Company and
Southwest Gas Corporation.
7
UTILITY SERVICES
SoCalGas' customers are separated, for regulatory purposes, into core
and noncore customers. Core customers are primarily residential and small
commercial and industrial customers, without alternative fuel capability.
Noncore customers primarily include utility electric generation ("UEG"),
wholesale and large commercial and industrial customers. Noncore customers are
especially sensitive to the price relationship between natural gas and alternate
fuels, and many are capable of readily switching from one fuel to another,
subject to air quality regulations.
SoCalGas offers two basic utility services, sale of gas and
transportation of gas. There are two business units at SoCalGas, one focusing
on core distribution customers and the other on large volume gas transportation
customers. Residential customers and most other core customers purchase gas
directly from SoCalGas. Noncore customers and large core customers have the
option of purchasing gas either from SoCalGas or from other sources (such as
brokers or producers) for delivery through SoCalGas' transmission and
distribution system. Smaller customers are permitted to aggregate their gas
requirements and also to purchase gas directly from brokers or producers, up to
a limit of 10 percent of SoCalGas' core market. SoCalGas generally earns the
same margin whether SoCalGas buys the gas and sells it to the customer or
transports gas already owned by the customer. (See "Item 7. Management's
Discussion and Analysis of Financial Condition and Results of Operations -
SoCalGas Operations - 1993-1995 Financial Results.")
SoCalGas continues to be obligated to purchase reliable supplies of
natural gas to serve the requirements of its core customers. However, the only
gas supplies that SoCalGas may offer for sale to noncore customers are the same
supplies that it purchases to serve its core customers.
SoCalGas also provides a gas storage service for noncore customers on
a bid basis. The storage service program provides opportunities for customers
to store gas on an "as available" basis during the summer to reduce winter
purchases when gas costs are generally higher, or to reduce their level of
winter curtailment in the event temperatures are unusually cold. As of December
31, 1995, SoCalGas stored approximately 42 billion cubic feet of customer-owned
gas.
DEMAND FOR GAS
Natural gas is a principal energy source in SoCalGas' service area for
residential, commercial and industrial uses as well as UEG requirements. Gas
competes with electricity for residential and commercial cooking, water heating,
space heating and clothes drying uses, and with other fuels for large
industrial, commercial and UEG uses. Demand for natural gas in southern
California is expected to continue to increase but at a slower rate due
primarily to a slowdown in housing starts, new energy efficient building
construction and appliance standards and general recessionary business
conditions.
During 1995, approximately 97 percent of residential energy customers
in SoCalGas' service territory used natural gas for water heating and 94 percent
for space heating. Approximately 78 percent of those customers used natural gas
for cooking and 72 percent for clothes drying.
Demand for natural gas by noncore customers such as large volume
commercial, industrial and UEG customers is very sensitive to the price of
alternative competitive fuels. These customers number only approximately 1,600;
however, during 1995, accounted for approximately 16 percent of total gas
revenues, 65 percent of total gas volumes delivered and 11 percent of the
8
authorized gas margin. Changes in the cost of gas or alternative fuels,
primarily fuel oil, can result in significant shifts in this market, subject to
air quality regulations. Demand for gas for UEG use is also affected by the
price and availability of electric power generated in other areas and purchased
by SoCalGas' UEG customers. (See "Competition" below.)
COMPETITION
Since interstate pipelines began operations in SoCalGas' service
territories, SoCalGas' throughput to customers in the Kern County area who use
natural gas to produce steam for enhanced oil recovery projects has decreased
significantly because of the bypass of SoCalGas' system. The decrease in
revenues from enhanced oil recovery customers is subject to full balancing
account treatment, except for a five percent incentive to SoCalGas, and
therefore, does not have a material impact on earnings. Bypass of other
SoCalGas markets also may occur and SoCalGas is fully at risk for lost noncore
volumes due to bypass. SoCalGas is continuing to reduce its costs to maintain
low-cost competitiveness to retain transportation customers. Also, significant
additional bypass would require construction of additional facilities by
competing pipelines.
To respond to bypass, SoCalGas has received authorization from the
CPUC for expedited review of long-term gas transportation contracts with some
noncore customers at lower than tariff rates. The CPUC has also approved
changes in the methodology for allocating SoCalGas' costs that eliminates
subsidization of core customer rates by noncore customers. This allocation
flexibility, together with negotiating authority, has enabled SoCalGas to better
compete with new interstate pipelines for noncore customers. In addition, under
a capacity brokering program, for a fee, SoCalGas provides to noncore customers,
or others, a portion of its control of interstate pipeline capacity to allow
more direct access to producers. Also, the Comprehensive Settlement (See "Item
7. Management's Discussion and Analysis of Financial Condition and Results of
Operations - Factors Influencing Future Financial Performance") improves
SoCalGas' competitiveness by reducing the cost of transportation service to
noncore customers.
SoCalGas' operations and those of its customers are affected by a
growing number of environmental laws and regulations. These laws and
regulations affect current operations as well as future expansion.
Historically, environmental laws have favorably impacted the use of natural gas
in SoCalGas' service territory, particularly by UEG customers and large
industrial customers. However, increasingly complex administrative and reporting
requirements of environmental agencies applicable to commercial and industrial
customers utilizing gas are not generally applicable to those using electricity.
On December 20, 1995, the CPUC issued a final decision to restructure
California electric utility regulation. Implementation of portions of the plan
is expected to need state legislative or federal administrative approval. The
CPUC's proposal has no immediate effect on SoCalGas' operations. However,
SoCalGas is continuing to evaluate the decision because future volumes of
natural gas it transports for electric utilities may be adversely affected by
increased use of electricity generated by out-of-state producers. UEG customers
currently account for 22 percent of SoCalGas' annual throughput. (See "Item 7.
Management's Discussion and Analysis of Financial Condition and Results of
Operation - Factors Influencing Future Financial Performance.") The
restructuring may also result in a reduction of electric rates to core
customers, but it is unlikely to overcome the entire cost advantage of natural
gas for existing residential uses.
9
SUPPLIES OF GAS
In 1995, SoCalGas delivered approximately 937 billion cubic feet of
natural gas through its system. Approximately 64 percent of these deliveries
were customer-owned gas for which SoCalGas provided transportation services,
compared to 65 percent in 1994. The balance of gas deliveries was gas purchased
by SoCalGas and resold to customers.
Most of the natural gas delivered by SoCalGas is produced outside of
California. These supplies are delivered to the SoCalGas' intrastate
transmission system by interstate pipeline companies (primarily El Paso Natural
Gas Company and Transwestern Natural Gas Company) that provide transportation
services for supplies purchased from other sources by SoCalGas or its
transportation customers.
SoCalGas currently has paramount rights to daily deliveries of up to
1.9 billion cubic feet of natural gas over the interstate pipeline systems of El
Paso Natural Gas Company (up to 1,150 million cubic feet) and Transwestern
Pipeline Company (up to 750 million cubic feet). The rates that interstate
pipeline companies may charge for gas and transportation services and other
terms of service are regulated by the Federal Energy Regulatory Commission
("FERC").
Existing interstate pipeline capacity into California exceeds current
demand by over 1 billion cubic feet per day. Up to 2 billion cubic feet per day
of capacity on the El Paso and Transwestern interstate pipeline systems,
representing over $175 million and $55 million, respectively, of reservation
charges annually, may be relinquished within the next few years. Some of this
capacity may not be resubscribed. Current FERC regulation could permit costs of
unsubscribed capacity to be allocated to remaining firm service customers,
including SoCalGas. Under existing regulation in California, SoCalGas would
have the opportunity to include its portion of any such reallocated costs in its
rates.
The FERC has approved a settlement with Transwestern which calls for
firm customers, including SoCalGas, to subsidize unsubscribed pipeline costs
for a five-year period with Transwestern assuming full responsibility after
that time. On March 15, 1996, El Paso filed a proposed settlement agreement
with the FERC that is similar to the Transwestern settlement.
The following table sets forth the sources of gas deliveries by
SoCalGas from 1991 through 1995.
10
SOURCES OF GAS
Year Ended December 31
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1995 1994 1993 1992 1991
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Gas Purchases (Millions of Cubic Feet):
Market Gas:
30-Day 133,298 98,071 84,696 20,695 139,649
Other 72,792 148,371 159,197 198,049 168,486
-------- ---------- --------- --------- -----------
Total Market Gas 206,090 246,442 243,893 218,744 308,135
Affiliates 98,460 101,276 96,559 99,226 98,566
California Producers &
Federal Offshore 29,181 36,158 28,107 42,262 39,613
-------- ---------- --------- --------- -----------
Total Gas Purchases 333,731 383,876 368,559 360,232 446,314
Customer-Owned Gas and
Exchange Receipts 619,721 658,293 622,307 641,080 629,038
Storage Withdrawal
(Injection) - Net (12,278) (9,299) (9,498) 14,379 (8,451)
Company Use and
Unaccounted For (4,061) (12,480) (16,488) (14,885) (19,433)
------- ---------- ---------- ---------- -----------
Net Gas Deliveries 937,113 1,020,390 964,880 1,000,806 1,047,468
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Gas Purchases: (Thousands of dollars)
Commodity Costs $477,595 $ 643,865 $ 815,145 $ 805,550 $1,071,445
Fixed Charges* 264,269 368,516 397,714 397,579 358,294
------- ----------- ---------- ---------- -----------
Total Gas Purchases $741,864 $1,012,381 $1,212,859 $1,203,129 $1,429,739
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Average Cost of Gas Purchased
(Dollars per Thousand Cubic Feet)** $1.42 $1.68 $2.21 $2.24 $2.40
--------- ----------- ---------- ---------- -----------
* Fixed charges primarily include pipeline demand charges, take or pay
settlement costs and other direct billed amounts allocated over the
quantities delivered by the interstate pipelines serving SoCalGas.
** The average commodity cost of gas purchased excludes fixed charges.
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Market sensitive gas supplies (supplies purchased on the spot
market as well as under longer-term contracts and ranging from one month to ten
years based on spot prices) accounted for approximately 62 percent of total gas
volumes purchased by SoCalGas during 1995, as compared with 64 percent and 66
percent, respectively, during 1994 and 1993. These supplies were generally
purchased at prices significantly below those for other long-term sources of
supply.
SoCalGas estimates that sufficient natural gas supplies will be
available to meet the requirements of its customers into the next century.
In 1994, the CPUC approved a "Gas Cost Incentive Mechanism"
("GCIM") for evaluating SoCalGas' gas purchases. The new GCIM three-year pilot
program that began in April 1994 substantially replaces the prior process of
CPUC reasonableness reviews of gas purchases. The GCIM compares SoCalGas' cost
of gas with the average market price of 30-day firm spot supplies delivered to
the SoCalGas service area and permits full recovery of all costs within a
tolerance band above that average. Cost of gas purchased above the tolerance
band or savings from gas purchased below the average market price are shared
equally between customers and shareholders. (See "Item 7. Management's
Discussion and Analysis of Financial Condition and Results of Operations -
SoCalGas Operations - Ratemaking Procedures.")
RATES AND REGULATION
SoCalGas is regulated by the CPUC. The CPUC consists of five
commissioners appointed by the Governor of California for staggered six-year
terms. It is the responsibility of the CPUC to determine that utilities operate
within the best interests of the ratepayer, with the opportunity to earn a
reasonable return on investment. The regulatory structure is complex and has a
very substantial impact on the profitability of SoCalGas.
Under current ratemaking procedures, the return that SoCalGas is
authorized to earn is the product of the authorized rate of return on rate base
and the amount of rate base. Rate base consists primarily of net investment in
utility plant. Thus, SoCalGas' earnings are affected by changes in the
authorized rate of return on rate base and changes in rate base and by SoCalGas'
ability to control expenses and investment in rate base within the amounts
authorized by the CPUC in setting rates. In addition, SoCalGas' ability to
achieve its authorized rate of return is affected by other regulatory and
operating factors. (See "Item 7. Management's Discussion and Analysis of
Financial Condition and Results of Operations - SoCalGas Operations - Ratemaking
Procedures.")
SoCalGas' operating and fixed costs, including return on rate
base, are allocated between core and noncore customers under a methodology that
is based upon the costs incurred in serving these customer classes. For 1996,
approximately 89 percent of the CPUC-authorized gas margin has been allocated to
core customers and 11 percent to noncore customers, including wholesale
customers. Under the current regulatory framework, costs may be reallocated
between the core and the noncore markets once every other year in a biennial
cost allocation proceeding ("BCAP").
SoCalGas has filed a PBR application with the CPUC to replace the
general rate case and certain other traditional regulatory proceedings. PBR, if
approved, would allow SoCalGas to be more responsive to consumer interests and
compete more effectively in contestable markets. Key elements of this proposal
include a permanent reduction in base rates of $42 million, an indexing measure
that would limit future base rate increases to the inflation rate less a
productivity factor and rate refunds to customers if service quality were to
deteriorate. This new approach would maintain cost based rates, but would link
financial performance with changes in
-12-
productivity. Although PBR could result in increased earnings volatility,
SoCalGas would have the opportunity to improve financial performance to the
extent it was able to reduce expenses, increase energy deliveries and generate
profits from new products and services.
Under the PBR proposal, SoCalGas would be at risk for certain
changes in interest rates and cost of capital, changes in core volumes not
caused by weather, and achievement of productivity improvements. The CPUC's
process for approval of PBR has been delayed pending determination of additional
information various parties desire to establish the starting base cost of
service. An agreement with several interested parties has been reached under
which SoCalGas will provide a substantial portion of the supporting
documentation that would be required for a general rate case proceeding. This
additional step will delay implementation beyond the proposed January 1, 1997
starting date.
PROPERTIES
At December 31, 1995, SoCalGas owned approximately 2,965 miles of
transmission and storage pipeline, 43,163 miles of distribution pipeline and
42,699 miles of service piping. It also owned 13 transmission compressor
stations and 6 underground storage reservoirs (with a combined working storage
capacity of approximately 115.3 billion cubic feet) and general office
buildings, shops, service facilities, and certain other equipment necessary in
the conduct of its business.
Southern California Gas Tower, a wholly owned subsidiary of
SoCalGas, has a 15 percent limited partnership interest in a 52-story office
building in downtown Los Angeles. SoCalGas leases, and currently occupies,
about half of the building. (See also "Item 2. Properties.")
ENERGY MANAGEMENT SERVICES
The Energy Management Services business unit of Pacific
Enterprises consists primarily of Pacific Interstate Company and Pacific Energy.
Through its subsidiaries, Pacific Interstate Company purchases
natural gas from producers in Canada and from federal waters offshore California
and transports it for resale to SoCalGas. Two subsidiaries own and operate
pipelines and related facilities for deliveries to SoCalGas of gas produced from
offshore fields near Santa Barbara, California. Another subsidiary has an
interest in pipeline facilities for deliveries to SoCalGas of gas from western
Canada. During 1995, deliveries from these subsidiaries accounted for
approximately 29% of the total volume of gas purchased by SoCalGas and
approximately 10% of SoCalGas' total throughput. The gas is purchased under
long-term contracts. (See "Item 7. Management's Discussion and Analysis of
Financial Condition and Results of Operations - Energy Management Services.")
Pacific Energy develops and operates alternate energy facilities
and operates centralized heating and cooling plants.
PACIFIC ENTERPRISES INTERNATIONAL
Pacific Enterprises International ("PEI") was established in late
1994 to participate in the international gas infrastructure market.
On March 19, 1996, PEI entered into an agreement to acquire a
12.5 percent interest in each of two natural gas utilities
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in Argentina. The acquisition price is $48.5 million. These utilities serve
about one million customers in central and southern Argentina with 625 million
cubic feet of gas per day. PEI expects to have a role in managing the utility
operations.
PEI has also entered into a memorandum of understanding with
San Diego Gas & Electric Co. and Proxima, S.A. de C.V. to build and operate
natural gas distribution networks in Mexico. The partnership's first
project, if awarded the franchise by the Mexican government, would be to
distribute gas to the City of Mexicali in Baja, California. This proposed
distribution network would have the capacity to deliver 80 million cubic feet
of gas per day. If approved by the government, licensing would take
approximately six months and actual construction of the pipeline and
facilities would require another six months.
ENVIRONMENTAL MATTERS
SoCalGas has identified and reported to California environmental
authorities 42 former gas manufacturing sites for which it (together with other
utilities as to 21 of the sites) may have remedial obligations under
environmental laws. As of December 31, 1995, nine of the sites have been
remediated, of which five have received certification from the California
Environmental Protection Agency. Preliminary investigations, at a minimum, have
been completed on 39 of the sites, including those sites at which the
remediations described above have been completed. In addition, the Company and
its subsidiaries are one of a large number of major corporations that have been
identified as a potentially responsible party for environmental remediation of
four industrial waste disposal sites and two landfill sites. These 47 sites are
in various stages of investigation or remediation. It is anticipated that the
investigation, and if necessary, remediation of these sites will be completed
over a period of from ten years to thirty years.
A settlement between SoCalGas and other California utilities and
the Division of Ratepayer Advocates provides for rate recovery of 90 percent of
environmental investigation and remediation costs without reasonableness review.
In addition, the utilities have the opportunity to retain a portion of any
insurance recovery to offset the 10 percent of costs not recovered in rates.
At December 31, 1995, SoCalGas' estimated remaining liability for
investigation and remediation was approximately $76 million, of which 90 percent
is authorized to be recovered through the rate recovery mechanism described
above. The estimated liability is subject to future adjustment pending further
investigation. (See "Item 7. Management's Discussion and Analysis of Financial
Condition and Results of Operation -- Factors Influencing Future Financial
Performance - Environmental Matters.") Because of current and expected rate
recovery, Pacific Enterprises believes that compliance with environmental laws
and regulations will not have a material adverse effect on its financial
statements.
EMPLOYEES
Pacific Enterprises and its subsidiaries employ approximately
7,900 persons. Of these, approximately 7,200 are employed by SoCalGas.
Most field, clerical and technical employees of SoCalGas are
represented by the Utility Workers' Union of America or the International
Chemical Workers' Union. Agreements covering these approximately 5,200
employees related to benefits expired in 1995 and an agreement covering wages,
hours and working conditions will expire on March 31, 1996. Negotiations
related to new contracts are ongoing.
-14-
MANAGEMENT
The executive officers of Pacific Enterprises are as follows:
Name Age Position
- ---- --- --------
Willis B. Wood, Jr. 61 Chairman of the Board and Chief Executive
Officer
Richard D. Farman 60 President and Chief Operating Officer
Larry J. Dagley 47 Senior Vice President and Chief Financial
Officer
Warren I. Mitchell 58 President, Southern California Gas Company
Frederick E. John 50 Senior Vice President
Debra L. Reed 39 Senior Vice President, Southern California
Gas Company
Lee M. Stewart 50 Senior Vice President, Southern California
Gas Company
Leslie E. LoBaugh, Jr. 50 Vice President and General Counsel
Ralph Todaro 45 Vice President and Controller
Executive officers are elected annually and serve at the pleasure of
the Board of Directors.
All of Pacific Enterprises' executive officers have been employed by
Pacific Enterprises or its subsidiaries in management positions for more than
five years, except for Mr. Dagley. From 1985, until joining Pacific Enterprises
in August, 1995, Mr. Dagley was Senior Vice President and Controller (1985-1993)
and Senior Vice President and Chief Financial Officer (1993-1995) of Transco
Energy Company.
There are no family relationships between any of Pacific Enterprises'
executive officers.
-15-
ITEM 2. PROPERTIES
Pacific Library Tower, a wholly-owned subsidiary of Pacific
Enterprises, sold its 25% ownership interest in a 72-story office building in
downtown Los Angeles as of January 1, 1996. Pacific Enterprises and its
subsidiaries lease twelve floors of the building.
Information with respect to the properties of other Pacific
Enterprises' subsidiaries is set forth in Item 1 of this Annual Report.
ITEM 3. LEGAL PROCEEDINGS
Except for the matters referred to in the financial statements filed
with or incorporated by reference in Item 8 or referred to elsewhere in this
Annual Report, neither Pacific Enterprises nor any of its subsidiaries is a
party to, nor is their property the subject of, any material pending legal
proceedings other than routine litigation incidental to its businesses.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
No matters were submitted during the fourth quarter of 1995 to a vote
of Pacific Enterprises' security holders.
-16-
PART II
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY
AND RELATED STOCKHOLDER MATTERS
Pacific Enterprises' Common Stock is traded on the New York and
Pacific Stock Exchanges. Information as to the high and low sales prices for
such stock as reported on the composite tape for stocks listed on the New York
Stock Exchange and dividends paid for each quarterly period during the two years
ended December 31, 1995 is set forth under the captions "Financial Review--Range
of Market Prices of Capital Stock" and "Quarterly Financial Data" in Pacific
Enterprises' 1995 Annual Report to Shareholders filed as Exhibit 13.01 to this
Annual Report. Such information is incorporated herein by reference.
At December 31, 1995, there were 39,217 holders of record of Pacific
Enterprises' Common Stock.
ITEM 6. SELECTED FINANCIAL DATA
The information required by this Item is set forth under the caption
"Financial Review - Selected Financial Data and Comparative Statistics 1985-
1995" in Pacific Enterprises' 1995 Annual Report to Shareholders filed as
Exhibit 13.01 to this Annual Report. Such information is incorporated herein by
reference.
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The information required by this Item is set forth under the caption
"Financial Review - Management's Discussion and Analysis" in Pacific
Enterprises' 1995 Annual Report to Shareholders filed as Exhibit 13.01 to this
Annual Report. Such information is incorporated herein by reference.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
Pacific Enterprises' consolidated financial statements and schedules
required by this Item are listed in Item 14(a)1 in Part IV of this Annual
Report. The consolidated financial statements listed in Item 14(a)1 are
incorporated herein by reference.
ITEM 9. CHANGES IN AND DISAGREEMENTS
WITH ACCOUNTANTS ON ACCOUNTING
AND FINANCIAL DISCLOSURE
None.
-17-
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
Information required by this Item with respect to the Company's
directors is set forth under the caption "Election of Directors" in the
Company's Proxy Statement for its Annual Meeting of Shareholders scheduled to be
held on May 9, 1996. Such information is incorporated herein by reference.
Information required by this Item with respect to the Company's
executive officers is set forth in Item 1 of this Annual Report.
ITEM 11. EXECUTIVE COMPENSATION
Information required by this Item is set forth under the caption
"Election of Directors" and "Executive Compensation" in the Company's Proxy
Statement for its Annual Meeting of Shareholders scheduled to be held on May 9,
1996. Such information is incorporated herein by reference.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN
BENEFICIAL OWNERS AND MANAGEMENT
Information required by this Item is set forth under the caption
"Election of Directors" in the Company's Proxy Statement for its Annual Meeting
of Shareholders scheduled to be held on May 9, 1996. Such information is
incorporated herein by reference.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED
TRANSACTIONS
None.
-18-
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT
SCHEDULES, AND REPORTS ON FORM 8-K
(a) DOCUMENTS FILED AS PART OF THIS REPORT
1. CONSOLIDATED FINANCIAL STATEMENTS.
1.01 Report of Deloitte & Touche LLP,
Independent Certified Public Accountants
(Contained in Exhibit 13.01).
1.02 Statement of Consolidated
Income for the years ended
December 31, 1995, 1994 and 1993
(Contained in Exhibit 13.01).
1.03 Consolidated Balance Sheet at
December 31, 1995 and 1994
(Contained in Exhibit 13.01).
1.04 Statement of Consolidated Cash Flows
for the years ended December 31, 1995,
1994 and 1993 (Contained in Exhibit 13.01).
1.05 Statement of Consolidated Shareholders'
Equity for the years ended
December 31, 1995, 1994 and 1993
(Contained in Exhibit 13.01).
1.06 Notes to Consolidated Financial
Statements (Contained in Exhibit 13.01).
3. ARTICLES OF INCORPORATION AND BY-LAWS:
3.01 Articles of Incorporation of
Pacific Enterprises
(Note 22; Exhibit 4.1).
3.02 Bylaws of Pacific Enterprises.
4. INSTRUMENTS DEFINING THE RIGHTS OF SECURITY HOLDERS:
(Note: As permitted by Item 601(b)(4)(iii) of Regulation S-K, certain
instruments defining the rights of holders of long-term debt for which
the total amount of securities authorized thereunder does not exceed
ten percent of the total assets of Southern California Gas Company and
its subsidiaries on a consolidated basis are not filed as exhibits to
this Annual Report. The Company agrees to furnish a copy of each such
instrument to the Commission upon request.)
4.01 Specimen Common Stock Certificate of
Pacific Enterprises (Note 16; Exhibit 4.01).
-19-
4.02 Specimen Preferred Stock Certificates of Pacific
Enterprises (Note 8; Exhibit 4.02).
4.03 Specimen Remarketed Preferred Stock
Certificate (Note 17; Exhibit 4.03).
4.04 First Mortgage Indenture of Southern California
Gas Company to American Trust Company dated
October 1, 1940 (Note 1; Exhibit B-4).
4.05 Supplemental Indenture of Southern California Gas
Company to American Trust Company dated as of
July 1, 1947 (Note 2; Exhibit B-5).
4.06 Supplemental Indenture of Southern California
Gas Company to American Trust Company dated as
of August 1, 1955 (Note 3; Exhibit 4.07).
4.07 Supplemental Indenture of Southern California
Gas Company to American Trust Company dated as
of June 1, 1956 (Note 4; Exhibit 2.08).
4.08 Supplemental Indenture of Southern California
Gas Company to Wells Fargo Bank, National
Association dated as of August 1, 1972 (Note 6;
Exhibit 2.19).
4.09 Supplemental Indenture of Southern California
Gas Company to Wells Fargo Bank, National
Association dated as of May 1, 1976 (Note 5;
Exhibit 2.20).
4.10 Supplemental Indenture of Southern California
Gas Company to Wells Fargo Bank, National
Association dated as of September 15, 1981
(Note 9; Exhibit 4.25).
4.11 Supplemental Indenture of Southern California
Gas Company to Manufacturers Hanover Trust
Company of California, successor to Wells
Fargo Bank, National Association, and Crocker
National Bank as Successor Trustee dated as
of May 18, 1984 (Note 11; Exhibit 4.29).
4.12 Supplemental Indenture of Southern California
Gas Company to Bankers Trust Company of
California, N.A., successor to Wells Fargo Bank,
National Association dated as of January 15,
1988 (Note 13; Exhibit 4.11).
-20-
4.13 Supplemental Indenture of Southern California Gas
Company to First Trust of California, National
Association, successor to Bankers Trust Company
of California, N.A. (Note 18; Exhibit 4.37).
4.14 Rights Agreement dated as of March 7, 1990
between Pacific Enterprises and Security
Pacific National Bank, as Rights
Agent (Note 19; Exhibit 4).
10. MATERIAL CONTRACTS
10.01 Form of Indemnification Agreement
between Pacific Enterprises and each of
its directors and officers
(Note 21; Exhibit 10.07).
EXECUTIVE COMPENSATION PLANS AND ARRANGEMENTS
10.2 Restatement and Amendment of Pacific
Enterprises 1979 Stock Option Plan
(Note 7; Exhibit 1.1).
10.3 Pacific Enterprises Supplemental Medical
Reimbursement Plan for Senior Officers
(Note 8; Exhibit 10.24).
10.4 Pacific Enterprises Financial Services
Program for Senior Officers (Note 8;
Exhibit 10.25).
10.5 Pacific Enterprises Supplemental
Retirement and Survivor Plan (Note 11;
Exhibit 10.36).
10.6 Pacific Enterprises Stock Payment
Plan (Note 11; Exhibit 10.37).
10.7 Pacific Enterprises Pension Restoration
Plan (Note 8; Exhibit 10.28).
10.8 Southern California Gas Company Pension
Restoration Plan For Certain Management
Employees (Note 8; Exhibit 10.29).
10.9 Pacific Enterprises Executive Incentive
Plan (Note 13; Exhibit 10.13).
10.10 Pacific Enterprises Deferred Compensation
Plan for Key Management Employees (Note 12;
Exhibit 10.41).
-21-
10.11 Pacific Enterprises Employee Stock
Ownership Plan and Trust Agreement
as amended in toto effective October 1, 1992.
(Note 21; Exhibit 10.18).
10.12 Pacific Enterprises Stock Incentive Plan
(Note 15; Exhibit 4.01).
10.13 Pacific Enterprises Retirement Plan for
Directors (Note 21; Exhibit 10.20).
10.14 Pacific Enterprises Director' Deferred
Compensation Plan (Note 21; Exhibit 10.21).
10.15 Pacific Enterprises Employee Stock Option Plan
(Note 23; Exhibit 4.01).
11. STATEMENT RE COMPUTATION OF PER SHARE EARNINGS
11.01 Pacific Enterprises Computation of
Earnings per Share (see Statement of
Consolidated Income contained in Exhibit 13.01).
13. ANNUAL REPORT TO SECURITY HOLDERS
13.01 Pacific Enterprises 1995 Annual
Report to Shareholders. (Such
report, except for the portions
thereof which are expressly
incorporated by reference in this
Annual Report, is furnished for the
information of the Securities and
Exchange Commission and is not to
be deemed "filed" as part of this
Annual Report).
21. SUBSIDIARIES OF THE REGISTRANT
21.01 List of subsidiaries of Pacific Enterprises.
23. CONSENTS OF EXPERTS AND COUNSEL
23.01 Consent of Deloitte & Touche LLP,
Independent Certified Public Accountants.
24. POWER OF ATTORNEY
24.01 Power of Attorney of Certain Officers
and Directors of Pacific Enterprises
(contained on signature pages).
27. FINANCIAL DATA SCHEDULE
27.01 Financial Data Schedule.
-22-
(b) REPORTS ON FORM 8-K:
No reports on Form 8-K were filed during the last quarter of 1995.
- -------------------------
NOTE: Exhibits referenced to the following notes were filed with
the documents cited below under the exhibit or annex number
following such reference. Such exhibits are incorporated
herein by reference.
Note
Reference Document
- --------- --------
1 Registration Statement No. 2-4504 filed by Southern California Gas Company
on September 16, 1940.
2 Registration Statement No. 2-7072 filed by Southern California Gas Company
on March 15, 1947.
3 Registration Statement No. 2-11997 filed by Pacific Lighting Corporation
on October 26, 1955.
4 Registration Statement No. 2-12456 filed by Southern California Gas
Company on April 23, 1956.
5 Registration Statement No. 2-56034 filed by Southern California Gas
Company on April 14, 1976.
6 Registration Statement No. 2-59832 filed by Southern California Gas
Company on September 6, 1977.
7 Registration Statement No. 2-66833 filed by Pacific Lighting Corporation
on March 5, 1980.
8 Annual Report on Form 10-K for the year ended December 31, 1980, filed by
Pacific Lighting Corporation.
9 Annual Report on Form 10-K for the year ended December 31, 1981, filed by
Pacific Lighting Corporation.
10 Annual Report on Form 10-K for the year ended December 31, 1983, filed by
Pacific Lighting Corporation.
11 Annual Report on Form 10-K for the year ended December 31, 1984, filed by
Pacific Lighting Corporation.
12 Annual Report on Form 10-K for the year ended December 31, 1985, filed by
Pacific Lighting Corporation.
13 Annual Report on Form 10-K for the year ended December 31, 1987, filed by
Pacific Enterprises.
14 Current Report on Form 8-K dated March 7, 1990, filed by Pacific
Enterprises.
15 Registration Statement No. 33-21908 filed by Pacific Enterprises on
May 17, 1988.
16 Annual Report on Form 10-K for the year ended December 31, 1988, filed by
Pacific Enterprises.
17 Annual Report on form 10-K for the year ended December 31, 1989, filed by
Pacific Enterprises.
-23-
18 Registration Statement No. 33-50826 filed by Southern California Gas
Company on August 13, 1992.
19 Current Report on Form 8-K dated September 25, 1992, filed by Pacific
Enterprises.
20 [Intentionally Left Blank.]
21 Annual Report on Form 10-K for the year ended December 31, 1992, filed by
Pacific Enterprises.
22 Registration Statement No. 33-61278 filed by Pacific Enterprises on
April 20, 1993.
23 Registration Statement No. 33-54055 filed by Pacific Enterprises on
June 9, 1994.
-24-
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities
Exchange Act of 1934, the Registrant has duly caused this report to be signed on
its behalf by the undersigned, thereunto duly authorized.
PACIFIC ENTERPRISES
By: WILLIS B. WOOD, JR./s/
-------------------------
Name: Willis B. Wood, Jr.
Title: Chairman of the Board and
Chief Executive Officer
Dated: March 20, 1996
-25-
Each person whose signature appears below hereby authorizes Willis B.
Wood, Jr., Richard D. Farman, and Larry J. Dagley, and each of them, severally,
as attorney-in-fact, to sign on his or her behalf, individually and in each
capacity stated below, and file all amendments to this Annual Report.
Pursuant to the requirements of the Securities Exchange Act of 1934,
this report has been signed below by the following persons on behalf of the
Registrant and in the capacities and on the dates indicated.
Signature Title Date
- --------- ------ ----
WILLIS B. WOOD, JR. /s/ Chairman of the Board, March 20, 1996
- ------------------------ Chief Executive Officer and
(Willis B. Wood, Jr.) Director (Principal Executive
Officer)
LARRY J. DAGLEY /s/ Senior Vice President and March 20, 1996
- ------------------------ Chief Financial Officer
(Larry J. Dagley) (Principal Financial Officer)
RALPH TODARO /s/ Vice President and Controller March 20, 1996
- ------------------------ (Principal Accounting Officer)
(Ralph Todaro)
HYLA H. BERTEA /s/ Director March 20, 1996
- ------------------------
(Hyla H. Bertea)
HERBERT L. CARTER /s/ Director March 20, 1996
- ------------------------
(Herbert L. Carter)
RICHARD D. FARMAN /s/ Director March 20, 1996
- ------------------------
(Richard D. Farman)
WILFORD D. GODBOLD, JR. /s/ Director March 20, 1996
- ------------------------
(Wilford D. Godbold, Jr.)
IGNACIO E. LOZANO, JR. /s/ Director March 20, 1996
- ------------------------
(Ignacio E. Lozano, Jr.)
HAROLD M. MESSMER, JR. /s/ Director March 20, 1996
- ------------------------
(Harold M. Messmer, Jr.)
PAUL A. MILLER /s/ Director March 20, 1996
- ------------------------
(Paul A. Miller)
RICHARD J. STEGEMEIER /s/ Director March 20, 1996
- ------------------------
(Richard J. Stegemeier)
DIANA L. WALKER /s/ Director March 20, 1996
- ------------------------
(Diana L. Walker)
-26-
BY LAWS
OF
PACIFIC ENTERPRISES
JUNE 6, 1995
BYLAWS
OF
PACIFIC ENTERPRISES
------
ARTICLE I
PRINCIPAL OFFICE
SECTION 1. The principal executive office of the Company
is located at 555 West Fifth Street, City of Los Angeles, County
of Los Angeles, California.
ARTICLE II
MEETINGS OF SHAREHOLDERS
SECTION 1. All Meetings of Shareholders shall be held
either at the principal executive office of the Company or at any
other place within or without the state as may be designated by
resolution of the Board of Directors.
SECTION 2. An Annual Meeting of Shareholders shall be
held each year on such date and at such time as may be designated
by resolution of the Board of Directors.
SECTION 3. At an Annual Meeting of Shareholders, only
such business shall be conducted as shall have been properly
brought before the Annual Meeting. To be properly brought before
an Annual Meeting, business must be (a) specified in the notice
of the Annual Meeting (or any supplement thereto) given by or at
the direction of the Board of Directors, (b) otherwise properly
brought before the Annual Meeting by a Shareholder. For business
to be properly brought before an Annual Meeting by a Shareholder,
including the nomination of any person (other than a person
nominated by or at the direction of the Board of Directors) for
election to the Board of Directors, the Shareholder must have
given timely and proper written notice to the Secretary of the
Company. To be timely, the Shareholder's written notice must be
received at the principal executive office of the Company not
less than sixty nor more than one hundred twenty days in advance
of the date corresponding to the date of the last Annual Meeting;
provided, however, that in the event the Annual Meeting to which
the Shareholder's written notice relates is to be held on a date
which differs by more than sixty days from the date corresponding
to the date of the last Annual Meeting, the Shareholder's written
notice to be timely must be so received not later than the close
of business on the tenth day following the date on which public
disclosure of the date of the Annual Meeting is made or given to
Shareholders. To be proper, the
Shareholder's written notice must set forth as to each matter the
Shareholder proposes to bring before the Annual Meeting (a) a
brief description of the business desired to be brought before
the Annual Meeting, (b) the name and address of the Shareholder
as they appear on the Company's books, (c) the class and number
of shares of the Company which are beneficially owned by the
Shareholder, and (d) any material interest of the Shareholder in
such business. In addition, if the Shareholder's written notice
relates to the nomination at the Annual Meeting of any person for
election to the Board of Directors, such notice to be proper must
also set forth (a) the name, age, business address and residence
address of each person to be nominated, (b) the principal
occupation or employment of each such person, (c) the number of
shares of capital stock beneficially owned by each such person,
and (d) such other information concerning each such person as
would be required under the rules of the Securities and Exchange
Commission in a proxy statement soliciting proxies for the
election of such person as a Director, and must be accompanied by
a consent, signed by each such person, to serve as a Director of
the Company if elected. Notwithstanding anything in the Bylaws
to the contrary, no business shall be conducted at an Annual
Meeting except in accordance with the procedures set forth in
this Section 3.
SECTION 4. Each Shareholder of the Company shall be
entitled to elect voting confidentiality as provided in this
Section 4 on all matters submitted to Shareholders by the Board
of Directors and each form of proxy, consent, ballot or other
written voting instruction distributed by the Company to
Shareholders shall include a check box or other appropriate
mechanism by which Shareholders who desire to do so may so elect
voting confidentiality.
All inspectors of election, vote tabulators and other
persons appointed or engaged by or on behalf of the Company to
process voting instructions (none of whom shall be a Director or
Officer of the Company or any of its affiliates) shall be advised
of and instructed to comply with this Section 4 and, except as
required or permitted hereby, not at any time to disclose to any
person (except to other persons engaged in processing voting
instructions), the identity and individual vote of any
Shareholder electing voting confidentiality; provided, however,
that voting confidentiality shall not apply and the name and
individual vote of any Shareholder may be disclosed to the
Company or to any person (i) to the extent that such disclosure
is required by applicable law or is appropriate to assert or
defend any claim relating to voting or (ii) with respect to any
matter for which votes of Shareholders are solicited in
opposition to any of the nominees or the recommendations of the
Board of Directors unless the persons engaged in such opposition
solicitation provide Shareholders of the Company with voting
confidentiality (which, if not otherwise provided, will be
requested by the Company) comparable in the opinion of the
Company to the voting confidentiality provided by this Section 4.
ARTICLE III
BOARD OF DIRECTORS
SECTION 1. The Board of Directors shall have power to:
a. Conduct, manage and control the business of the
Company, and make rules consistent with law, the Articles of
Incorporation and the Bylaws;
-2-
b. Elect, and remove at their discretion, Officers of the
Company, prescribe their duties, and fix their compensation;
c. Authorize the issue of shares of stock of the Company
upon lawful terms: (i) in consideration of money paid, labor
done, services actually rendered to the Company or for its
benefit or in its reorganization, debts or securities
cancelled, and tangible or intangible property actually
received either by this Company or by a wholly-owned
subsidiary; but neither promissory notes of the purchaser
(unless adequately secured by collateral other than the
shares acquired or unless permitted by Section 408 of the
California Corporations Code) nor future services shall
constitute payment or part payment for shares of this
Company, or (ii) as a share dividend or upon a stock split,
reverse stock split, reclassifications of outstanding shares
into shares of another class, conversion of outstanding
shares into shares of another class, exchange of outstanding
shares for shares of another class or other change affecting
outstanding shares;
d. Borrow money and incur indebtedness for the purposes of
the Company, and cause to be executed and delivered, in the
Company name, promissory notes, bonds, debentures, deeds of
trust, mortgages, pledges, hypothecations or other evidences
of debt;
e. Elect an Executive Committee and other committees.
SECTION 2. The Board of Directors shall elect an
Executive Committee from the Directors, which shall consist of
five members including the Chairman of the Board and the
President. The Board may designate one of the members of the
Executive Committee as the Chairman of the Executive Committee
and may also designate one or more Directors as alternate members
of the Executive Committee, who may replace any absent member at
any meeting of the Executive Committee. Subject to change by
resolution adopted by the Board of Directors or the Executive
Committee, meetings of the Executive Committee shall be called
and held at times and places fixed by the Chairman of the Board,
the Chairman of the Executive Committee, or any two members of
the Executive Committee; notice of meetings shall be given in the
manner described in the Bylaws for giving notice of special
meetings of the Board of Directors; the Chairman of the Executive
Committee shall preside and, in his absence, the Chairman of the
Board shall be the presiding officer. The Executive Committee
shall have all the authority of the Board of Directors except
with respect to (a) the approval of any action for which
California General Corporation Law also requires shareholders'
approval or approval of the outstanding shares; (b) the filling
of vacancies on the Board or in any committee; (c) the fixing of
compensation of the Directors for serving on the Board or on any
committee; (d) the amendment or repeal of Bylaws or the adoption
of new bylaws; (e) the amendment or repeal of any resolution of
the Board which by its express terms is not so amendable or
repealable; (f) a distribution, except at a rate, in a periodic
amount or within a price range set forth in the Articles of
Incorporation or determined by the Board; (g) the appointment of
other committees of the Board or the members thereof; and (h) the
fixing of compensation of officers of the Company or its
subsidiaries. A majority of the authorized number of members of
the Executive Committee shall constitute a quorum for the
transaction of business.
-3-
SECTION 3. The Board of Directors shall consist of not
less than nine nor more than seventeen members. The exact number
of Directors shall be fixed from time to time, within the limits
specified, by a resolution duly adopted by the Board of
Directors. A majority of the authorized number of Directors
shall constitute a quorum of the Board.
ARTICLE IV
MEETING OF DIRECTORS
SECTION 1. Meetings of the Board of Directors shall be
held at any place which has been designated by resolution of the
Board of Directors, or by written consent of all members of the
Board. In the absence of such designation, regular meetings
shall be held in the principal executive office.
SECTION 2. Immediately following each Annual Meeting of
Shareholders there shall be a regular meeting of the Board of
Directors for the purpose of organization, election of Officers
and the transaction of other business. In all months other than
May in which the Annual Meeting of Shareholders is held there
shall be a regular meeting of the Board of Directors on the first
Tuesday of each month at such hour as shall be designated by
resolution of the Board of Directors. Notice of regular meetings
of the Directors shall be given in the manner described in these
Bylaws for giving notice of special meetings. No notice of the
regular meeting of Board of Directors which follows the Annual
Meeting of Shareholders need be given.
SECTION 3. Special meetings of the Board of Directors
for any purpose may be called at any time by the Chairman of the
Board or, if he is absent or unable or refuses to act, by the
President, any Vice President who is a Director, or by any seven
Directors. Notice of the time and place of special meetings
shall be given to each Director. In case notice is mailed or
telegraphed, it shall be deposited in the United States mail or
delivered to the telegraph company in the city in which the
principal executive office is located at least twenty hours prior
to the time of the meeting. In case notice is given personally
or by telephone, it shall be delivered at least six hours prior
to the time of the meeting.
SECTION 4. The transactions of any meeting of the Board
of Directors, however called or noticed, shall be as valid as
though in a meeting duly held after regular call and notice if a
quorum be present and each of the Directors, either before or
after the meeting, signs a written waiver of notice, a consent to
holding such meeting, or an approval of the minutes thereof or
attends the meeting without protesting, prior thereto or at its
commencement, the lack of notice to such Director. All such
waivers, consents or approvals shall be made a part of the
minutes of the meeting.
SECTION 5. If any regular meeting of Shareholders or of
the Board of Directors falls on a legal holiday, then such
meeting shall be held on the next succeeding business day at the
same hour. But a special meeting of Shareholders or Directors
may be held upon a holiday with the same force and effect as if
held upon a business day.
-4-
ARTICLE V
OFFICERS
SECTION 1. The Officers of the Corporation shall be a
Chairman of the Board, a President, Vice President, one or more
of whom, in the discretion of the Board of Directors, may be
appointed Executive Vice President, a Secretary and a Treasurer.
The Company may have, at the discretion of the Board of
Directors, any other Officers and may also have, at the
discretion of and upon appointment by the Chairman of the Board,
one or more Assistant Secretaries and Assistant Treasurers. One
person may hold two or more offices.
ARTICLE VI
THE CHAIRMAN OF THE BOARD AND THE PRESIDENT
SECTION 1. The Chairman of the Board of Directors shall
be a member of the Board and the Chief Executive Officer of the
Company and shall preside at all Meetings of Shareholders and the
Board. The Chairman of the Board shall have general charge and
supervision of the Company's business and all of its Officers,
employees and agents and he shall have all of the powers and
perform all of the duties inherent in that office. The Chairman
of the Board shall have additional powers and perform further
duties as may be prescribed by the Board of Directors.
SECTION 2. The President shall be a member of the Board
and the Chief Operating Officer of the Company. The President
shall have all of the powers and perform all of the duties
inherent in that office. The President shall have additional
powers and perform further duties as may be prescribed by the
Board of Directors.
ARTICLE VII
VICE PRESIDENTS
SECTION 1. In the Chairman's and the President's
absence, disability or refusal to act, the Vice Presidents in
order of their rank shall perform all of the duties of the
Chairman and the President and when so acting shall have all of
the powers and be subject to all of the restrictions of the
Chairman and the President. The Vice Presidents shall have such
other powers and perform such additional duties as may be
prescribed by the Board of Directors or the Chief Executive
Officer.
ARTICLE VIII
SECRETARY
SECTION 1. The Secretary shall keep at the principal
executive office, a book of minutes of all meetings of Directors
and Shareholders, which shall contain a statement of the time and
place of the meeting, whether it was regular or special and, if
special, how authorized and the
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notice given, the names of those present at Directors' meetings,
the number of shares present or represented by written proxy at
Shareholders' meetings and the proceedings.
SECTION 2. The Secretary shall give notice of all
meetings of Shareholders and the Board of Directors required by
the Bylaws or by law to be given, and shall keep the seal of the
Company in safe custody. The Secretary shall have such other
powers and perform such additional duties as may be prescribed by
the Board of Directors or the Chief Executive Officer.
SECTION 3. It shall be the duty of the Assistant
Secretaries to help the Secretary in the performance of the
Secretary's duties. In the absence or disability of the
Secretary, the Secretary's duties may be performed by an
Assistant Secretary.
ARTICLE IX
TREASURER
SECTION 1. The Treasurer shall have custody and account
for all funds or moneys of the Company which may be deposited
with the Treasurer, or in banks, or other places of deposit. The
Treasurer shall disburse funds or moneys which have been duly
approved for disbursement. The Treasurer shall sign notes, bonds
or other evidences of indebtedness for the Company as the Board
of Directors may authorize. The Treasurer shall perform such
other duties which may be assigned by the Board of Directors or
the Chief Executive Officer.
SECTION 2. It shall be the duty of the Assistant
Treasurers to help the Treasurer in the performance of the
Treasurer's duties. In the absence or disability of the
Treasurer, the Treasurer's duties may be performed by an
Assistant Treasurer.
ARTICLE X
RECORD DATE
SECTION 1. The Board of Directors may fix a time in the
future as a record date for ascertaining the Shareholders
entitled to notice and to vote at any meeting of Shareholders, to
give consent to corporate action in writing without a meeting, to
receive any dividend, distribution, or allotment of rights or to
exercise rights related to any change, conversion, or exchange of
shares. The selected record date shall not be more than sixty
nor less than 10 days prior to the date of the Meeting nor more
than sixty days prior to any other action or event for the
purposes for which it is fixed. When a record date is fixed,
only Shareholders of Record on that date are entitled to notice
and to vote at the Meeting, to give consent to corporate action,
to receive a dividend, distribution, or allotment of rights, or
to exercise any rights in respect of any other lawful action,
notwithstanding any transfer of shares on the books of the
Company after the record date. The record date for determining
Shareholders, entitled to give consent to corporate action in
writing without a Meeting, when no prior action by the Board has
been taken, shall be the sixtieth calendar day following the day
on which the first consent is delivered to the Secretary.
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ARTICLE XI
INDEMNIFICATION OF AGENTS OF THE COMPANY;
PURCHASE OF LIABILITY INSURANCE
SECTION 1. For the purposes of this Article, "agent"
means any person who is or was a Director, Officer, employee or
other agent of the Company, or is or was serving at the request
of the Company as a director, officer, employee or agent of
another foreign or domestic corporation, partnership, joint
venture, trust or other enterprise, or was a director, officer,
employee or agent of a foreign or domestic corporation which was
a predecessor corporation of the Company or of another enterprise
at the request of such predecessor corporation; "proceeding"
means any threatened, pending or completed action or proceeding,
whether civil, criminal, administrative, or investigative; and
"expenses" includes, without limitation, attorneys' fees and any
expenses of establishing a right to indemnification under
Section 4 or paragraph (d) of Section 5 of this Article.
SECTION 2. The Company shall indemnify any person who
was or is a party, or is threatened to be made a party, to any
proceeding (other than an action by or in the right of the
Company to procure a judgment in its favor) by reason of the fact
that such person is or was an agent of the Company, against
expenses, judgments, fines, settlements and other amounts
actually and reasonably incurred in connection with such
proceeding if such person acted in good faith and in a manner
such person reasonably believed to be in the best interests of
the Company, and, in the case of a criminal proceeding, had no
reasonable cause to believe the conduct of such person was
unlawful. The termination of any proceeding by judgment, order,
settlement, conviction or upon a plea of nolo contendere or its
equivalent shall not, of itself, create a presumption that the
person did not act in good faith and in a manner which the person
reasonably believed to be in the best interests of the Company or
that the person had reasonable cause to believe that the person's
conduct was unlawful.
SECTION 3. The Company shall indemnify any person who
was or is a party or is threatened to be made a party to any
threatened, pending or completed action by or in the right of the
Company to procure a judgment in its favor by reason of the fact
that such person is or was an agent of the Company, against
expenses actually and reasonably incurred by such person in
connection with the defense or settlement of such action if such
person acted in good faith and in a manner such person believed
to be in the best interests of the Company and its Shareholders.
No indemnification shall be made under this Section 3 for
any of the following:
a. In respect of any claim, issue or matter as to which
such person shall have been adjudged to be liable to the
Company in the performance of such person's duty to the
Company and its Shareholders, unless and only to the extent
that the court in which such proceeding is or was pending
shall determine upon application that, in view of all the
circumstances of the case, such person is fairly and
reasonably entitled to indemnity for expenses and then only
to the extent that the court shall determine;
-7-
b. Of amounts paid in settling or otherwise disposing of a
pending action without court approval;
c. Of expenses incurred in defending a pending action
which is settled or otherwise disposed of without court
approval.
SECTION 4. To the extent that an agent of the Company
has been successful on the merits in defense of any proceeding
referred to in Section 2 or 3 or in defense of any claim, issue
or matter therein, the agent shall be indemnified against
expenses actually and reasonably incurred by the agent in
connection therewith.
SECTION 5. Except as provided in Section 4, any
indemnification under this Article shall be made by the Company
only if authorized in the specific case, upon a determination
that indemnification of the agent is proper in the circumstances
because the agent has met the applicable standard of conduct set
forth in Section 2 or 3, by any of the following:
a. A majority vote of a quorum consisting of Directors who
are not parties to such proceeding;
b. If such a quorum of Directors is not obtainable, by
independent legal counsel in a written Opinion;
c. Approval of the Shareholders, with the shares owned by
the person to be indemnified not being entitled to vote
thereon;
d. The court in which such proceeding is or was pending
upon application made by the Company or the agent or the
attorney or other person rendering services in connection
with the defense, whether or not such application by the
agent, attorney or other person is opposed by the Company.
SECTION 6. Expenses incurred in defending any proceeding
may be advanced by the Company prior to the final disposition of
such proceeding upon receipt of an undertaking by or on behalf of
the agent to repay such amount if it shall be determined
ultimately that the agent is not entitled to be indemnified as
authorized in this Article.
SECTION 7. The indemnification provided by this Article
shall not be deemed exclusive of any other rights to which those
seeking indemnification may be entitled under any agreement, vote
of Shareholders or disinterested Directors or otherwise, to the
extent such additional rights to indemnification are authorized
in the Articles of Incorporation of the Company. The rights to
indemnity under this Article shall continue as to a person who
has ceased to be a Director, Officer, employee, or agent and
shall inure to the benefit of the heirs, executors and
administrators of the person.
-8-
SECTION 8. No indemnification or advance shall be made
under this Article, except as provided in Section 4 or
paragraph (d) of Section 5, in any circumstance where it appears:
a. That it would be inconsistent with a provision of the
Articles of Incorporation, these Bylaws, a resolution of the
Shareholders or an agreement in effect at the time of the
accrual of the alleged causes of action asserted in the
proceeding in which the expenses were incurred or other
amounts were paid, which prohibits or otherwise limits
indemnification;
b. That it would be inconsistent with any condition
expressly imposed by a court in approving a settlement.
SECTION 9. The Company shall have the power to purchase
and maintain insurance on behalf of any agent of the Company
against any liability asserted against or incurred by the agent
in such capacity or arising out of the agent's status as such
whether or not the Company would have the power to indemnify the
agent against such liability under the provisions of this
Article.
SECTION 10. This Article does not apply to any proceeding
against any trustee, investment manager or other fiduciary of an
employee benefit plan in such person's capacity as such, even
though such person may also be an agent of the Company as defined
in Section 1. Nothing contained in this Article shall limit any
right to indemnification to which such a trustee, investment
manager or other fiduciary may be entitled by contract or
otherwise, which shall be enforceable to the extent permitted by
applicable law.
ARTICLE XII
SEAL
SECTION 1. The Company shall have a common seal upon
which shall be inscribed:
"Pacific Enterprises
Incorporated May 21, 1907
California"
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555 West 5th Street
Suite 2900
Los Angeles, California 90013-1011
213 895 5000
PACIFIC ENTERPRISES 1995 ANNUAL REPORT
[PHOTO]
IN RESPONSE TO the changing energy marketplace, Pacific Enterprises continued
its evolution from a utility holding company to an energy services company. We
improved our competitive position with a strategic realignment and took
additional steps toward more market-based regulation for our utility operations.
ABOUT THE COVER: The illustrations on the cover and elsewhere in this report,
are representative of the key strategies that are guiding Pacific Enterprises
through its transition to an energy services company. They depict our response
to the forces of change that are fundamentally altering the way energy utilities
operate and our role in a competitive market economy.
TABLE OF CONTENTS
Letter to Shareholders 3
Fundamental Strategies: A Progress Report 10
Glossary of Terms & Abbreviations 19
Financial Review 22
Directors & Officers 57
Corporate Information IBC
THE PACIFIC ENTERPRISES COMPANIES VISION
PAGE 1
WE ARE A DYNAMIC, world-class energy services company that places customers
first.
Committed, competent people working together, we are driven by a fierce resolve
to succeed in a constantly changing competitive environment.
HIGHLIGHTS
PAGE 2 PACIFIC ENTERPRISES
Year Ended December 31
-------------------------------------------------
(Dollars are in millions, except share and per-share amounts) 1995 1994 1993
- --------------------------------------------------------------------------------------------------------------
CONSOLIDATED FINANCIAL DATA
Operating Revenues $ 2,343 $ 2,664 $ 2,899
Net Income $ 185 $ 172 $ 181
Net Income Per Share of Common Stock $ 2.12 $ 1.95 $ 2.06
Weighted Average Number of Common Shares
Outstanding (thousands) 82,265 81,939 80,472
Total Assets $ 5,259 $ 5,445 $ 5,596
Common Dividends Paid Per Share $ 1.34 $ 1.26 $ .60
Dividend Payout Ratio 63% 65% 29%
Debt to Total Capitalization 50% 55% 54%
Book Value Per Share $ 15.71 $ 14.74 $ 12.19
Year-End Share Price $ 28 1/4 $ 21 1/4 $ 23 3/4
SOUTHERN CALIFORNIA GAS COMPANY STATISTICS
Annual Throughput (billions of cubic feet):
Core 325 341 339
Noncore 612 679 626
- --------------------------------------------------------------------------------------------------------------
Total 937 1,020 965
Average Cost of Gas Purchased $ 1.42 $ 1.68 $ 2.21
Number of Customers (millions) 4.7 4.7 4.7
Weighted Average Rate Base $ 2,766 $ 2,862 $ 2,769
Book Value Per Share of PE Common Stock $ 17.57 $ 18.00 $ 17.13
Achieved Return on Common Equity 13.89% 12.33% 12.96%
Authorized Return on Common Equity 12.00% 11.00% 11.90%
- --------------------------------------------------------------------------------------------------------------
THE HIGHLIGHTS SHOULD BE READ IN CONJUNCTION WITH MANAGEMENT'S DISCUSSION AND
ANALYSIS AND CONSOLIDATED FINANCIAL STATEMENTS IN ORDER FOR THE READER TO
UNDERSTAND FULLY THE SIGNIFICANCE OF THESE SUMMARY FIGURES.
CORPORATE DESCRIPTION Pacific Enterprises is a Los Angeles-based utility
holding company whose principal subsidiary is Southern California Gas Company,
the nation's largest natural gas distribution utility. Pacific Enterprises also
has interests in interstate and offshore natural gas pipelines, electricity
generation through alternate energy sources and centralized heating and cooling
operations for large building complexes.
TO OUR SHAREHOLDERS:
PAGE 3 PACIFIC ENTERPRISES
By any measure, 1995 was a year of continued successful progress and change for
Pacific Enterprises. Consider these achievements:
- - In response to the changing energy marketplace, we continued our evolution
from a utility holding company to an energy services company. As part of that
change, we reorganized the Pacific Enterprises Companies into five business
units to position us to be an even more effective competitor.
- - Southern California Gas Company, our largest subsidiary, filed a performance
based regulation proposal with the California Public Utilities Commission to
begin the transition from traditional cost-of-service utility regulation, and
to seek wider latitude to offer competitively priced new products and
services.
- - And we had an outstanding year financially, earning $2.12 per share of common
stock, up 9 percent over 1994. We achieved a 41 percent total return to
shareholders, a performance that exceeded the average total return of 31
percent for our top 10 utility peers across the nation and beat the Standard
& Poor's index of 500 stocks by 3 percentage points.
Overall we currently enjoy our strongest financial position in recent
years. As evidence of these accomplishments, our credit ratings today are at
their highest levels since the early 1980s for Pacific Enterprises, and since
1974 for our utility operations.
STRATEGIC REALIGNMENT
During 1995 we realigned the PE Companies into five business units. We did this
to bring our collective resources closer to our customers and sharpen our
customer focus. In doing so, we created two business units at SoCalGas and three
new business units to pursue opportunities for new products and services and to
compete in new markets both at home and overseas.
We also improved our operating efficiencies, giving us greater flexibility
to respond to competitors. The realignment results in estimated annual pre-tax
cost savings of $59 million, as we continue to focus on becoming the low-cost
provider of services to our customers.
CONSOLIDATED FINANCIAL RESULTS
Net income for Pacific Enterprises for 1995 was $185 million, or $2.12 per
share, compared with net income of $172 million, or $1.95 per share, a year ago.
Our strong earnings and cash flow allowed us to increase the dividend on common
stock in 1995 by 6 percent to an annualized level of $1.36 per share.
Our excellent financial performance in 1995 was driven by the solid results
of Southern California Gas Company, the nation's largest natural gas
distribution utility.
UTILITY FINANCIAL RESULTS
SoCalGas posted earnings of $203 million in 1995, a 13 percent increase over
1994 earnings. The utility's earnings rose primarily because of two factors.
First, California regulators increased the utility's authorized return on equity
to 12 percent for the year, compared with 11 percent in 1994. Second, SoCalGas
continued to lower its operating costs, the result of improved operating
efficiencies attained while continuing to provide safe and reliable utility
service.
As a result of these efforts, SoCalGas extended its enviable record to 13
straight years of meeting or exceeding the rate of return authorized by the
California Public Utilities Commission (CPUC).
UTILITY OPERATIONS
On the operating side, the utility's total rate base declined slightly. This was
due to reduced capital spending that reflected slow growth in the local economy
and to continued economizing at the utility in anticipation of a future
regulatory structure in which earnings growth is based on performance incentives
rather than increasing assets. Despite the capital spending decline, SoCalGas
added 41,000 new meters to
LETTER TO SHAREHOLDERS
PAGE 4 PACIFIC ENTERPRISES
its 4.7 million-meter base. The lower rate base did not hurt 1995 earnings
because rates for the year reflected previously established growth estimates.
Total natural gas throughput declined by 8 percent to 937 billion cubic
feet for 1995, as electric utilities in southern California bypassed local gas-
fired electric generation to buy less expensive hydro-electric supplies. Despite
this decline, however, throughput remained above the forecast established in
rates.
OTHER OPERATIONS
Parent company and other operations reported a $4 million after-tax loss for
1995, compared with $4 million net income in 1994. These results reflected a $4
million (5 cents per share) after-tax reserve established in the second quarter
related to resolving certain power sales contract issues at our alternate energy
subsidiary. They also reflected start-up costs associated with two new business
units established under the strategic realignment.
Other operations include our alternate energy and interstate pipeline
facilities. In 1995 our alternate energy plants produced 866,000 megawatt-hours
of electricity, enough power to serve a city of about 140,000 households. Our
interstate pipelines delivered 99 billion cubic feet of gas from Canada and
offshore California to SoCalGas during the year, 29 percent of SoCal's gas
purchases for the year.
PE COMPANIES OUTLOOK
For 1996 our earnings will be driven by these key factors:
- - AUTHORIZED ROE The CPUC reduced the authorized return on equity for SoCalGas
in 1996 by 40 basis points to 11.6 percent. A change of 100 basis points in
ROE results in a change of net income by $13 million (16 cents per common
share). At the same time, the commission allowed a 40-basis-point increase in
the common equity component of the utility's capital structure to 47.4
percent. On a rate base of $2.8 billion, this increase could help earnings by
$1 million to $2 million.
- - COST SAVINGS VS. PRODUCTIVITY TARGETS Under terms of a Comprehensive
Settlement approved by the CPUC in 1994, SoCalGas must realize greater
"productivity" savings in its 1996 operations -- a 3 percent reduction in
operating and maintenance costs, compared with 2 percent in 1995.
Shareholders will benefit from cost savings at the utility only to the extent
that they exceed the productivity target. SoCalGas expects to manage its
operations in 1996 so that it will at least meet the productivity target.
- - NONCORE THROUGHPUT A third factor involves the total gas volumes SoCalGas
delivers to its noncore customers. The utility is at risk for revenue
shortfalls that would occur if deliveries to these customers fall below the
estimates adopted by the CPUC in establishing rates.
Other factors include negotiations on a new wages and working conditions
contract for union employees and the economic health of our primary market area-
southern California. New housing permits in southern California are expected to
grow at 40,000 to 45,000 annually over the next five years, and this should
approximate our utility's new customer growth.
DIVIDEND POLICY
The dividend policy established by our Board of Directors remains unchanged. Our
goal is to increase our payout as a percentage of earnings over time to be in
line with the historical payout levels of our gas distribution peers. Our 1995
payout stood at 63 percent, while the historic payout level for our peers was in
the range of 70 to 80 percent. The dividend is a key element of the total return
shareholders realize on their investment in Pacific Enterprises, and we focus on
total return as a benchmark of our performance.
While we believe our stock price increase during the year recognized our
successes in
PAGE 5 PACIFIC ENTERPRISES
[PHOTO]
PACIFIC ENTERPRISES EXECUTIVE COUNCIL: SEATED (LEFT) Willis B. Wood Jr., Richard
D. Farman. STANDING (FROM LEFT) Debra L. Reed, Larry J. Dagley, Claude Harvey,
Warren I. Mitchell,
G. Joyce Rowland, Christopher R. Sherman, Lee M. Stewart, Frederick E. John,
Anne M. Miller.
LETTER TO SHAREHOLDERS
PAGE 6 PACIFIC ENTERPRISES
1995, we also realize that part of this appreciation can be attributed to the
year's 24 percent decline in long-term interest rates and the general strength
of the market itself.
Finally, any outlook for the PE Companies must address the question of what
we intend to do with our cash in short-term investments, which totalled $335
million at year-end. We have considered a variety of options and have concluded
to redeem up to $210 million of preferred stock -- $110 million of Pacific
Enterprises remarketed preferred and $100 million of SoCalGas auction preferred.
Redeeming these shares takes a variable cost component out of our capital
structure and reduces the preferred component of that structure to a level more
comparable to our peers. Redemption also results in an annual savings of
approximately $2.4 million, or 3 cents per share, to the benefit of our common
shareholders.
After these redemptions we will continue to have sufficient cash to fund
new products and services, new business opportunities and for general corporate
needs. Any remaining cash in excess of these needs will be returned to
shareholders in some way.
INDUSTRY OUTLOOK
We are convinced that the competitive, regulatory and technological forces that
have converged on the energy industry will continue, if not accelerate, in 1996.
Electric industry restructuring, which is moving ahead in California and other
states, will be a major driver of change. As a result, strategic alliances,
mergers and acquisitions will continue to re-shape our industry as companies
attempt to position themselves for a more competitive environment.
Our vision to be a world class energy services company remains unchanged.
We expect 1996 to be a challenging year as we continue to adjust to the
uncertainties of a more competitive market. We are confident, however, that we
have the right organizational structure and the right people in place to meet
these challenges, and we are very excited about the opportunities that await the
Pacific Enterprises Companies in the new competitive environment.
PERSONNEL CHANGES
In May retired Unocal Corporation Chairman and Chief Executive Officer Richard
J. Stegemeier was elected to our Board of Directors. We are pleased to have Mr.
Stegemeier's counsel and the benefit of his more than 40 years of experience,
both foreign and domestic, in the energy industry.
Larry J. Dagley joined the PE Companies in August as Senior Vice President
and Chief Financial Officer. Mr. Dagley held the same position at the Houston-
based Transco Energy Company, which, during his tenure, moved from operating in
a closely regulated environment to one that was more market oriented.
Christopher R. Sherman was named President of Pacific Enterprises
International in September. Mr. Sherman had overseen PEI'S operations on an
interim basis since the company's inception while serving as Senior Vice
President of Pacific Enterprises and head of the new Energy Management Services
business unit. His replacement has not yet been named.
/s/Willis B. Wood Jr.
Willis B. Wood Jr.
CHAIRMAN AND CHIEF EXECUTIVE OFFICER
/s/Richard D. Farman
Richard D. Farman
PRESIDENT AND CHIEF OPERATING OFFICER
February 12, 1996
PAGE 7 PACIFIC ENTERPRISES
[PHOTO]
Willis B. Wood Jr.
CHAIRMAN AND CHIEF
EXECUTIVE OFFICER
Richard D. Farman
PRESIDENT AND CHIEF
OPERATING OFFICER
[PHOTO]
MAINTAINING
UTILITY PROFITABILITY
PE's southern California operations are today's primary driver for growth in
both regulated and unregulated businesses. To maintain the profitability of
these operations, the utility is saving costs to hone its competitive edge and
offering new services to new customers, like reconditioning gas meters for one
utility and reading water meters for another.
[PHOTO]
FUNDAMENTAL STRATEGIES: A PROGRESS REPORT
PAGE 10 PACIFIC ENTERPRISES
INTRODUCTION
Pacific Enterprises entered 1995 focused on three fundamental strategies for
realizing its vision of becoming a dynamic, world-class energy services company.
These strategies were to:
- - Maintain profitability of the utility.
- - Leverage core competencies to achieve growth.
- - Realign the organization to achieve success.
With a workforce committed to the long-term growth and success of the
Pacific Enterprises Companies as a whole, PE has taken significant steps to
achieve its vision. The following report details this progress.
BACKGROUND
The PE Companies have a significant stake in southern California. PE's largest
subsidiary, Southern California Gas Company, is the nation's largest natural gas
distribution utility, providing service to more than 17 million people through
4.7 million meters.
Most of these meters serve core customers -- residential and small
commercial users. About 1,600 meters serve noncore customers -- large-volume
users, such as industrial facilities and electricity-generating utilities.
Within its residential market SoCalGas provides the fuel for 94 percent of
space heaters, 97 percent of water heaters, 78 percent of cooking appliances and
72 percent of clothes dryers.
This is a huge presence in one of the best natural gas markets in the
nation. At the same time, however, it also is one of the nation's most contested
markets.
COMPETITIVE CHALLENGES
Competitors, including interstate pipelines, gas brokers and even
municipalities, continue to pressure SoCalGas by seeking to serve its customers
directly or offer traditional utility services, such as gas procurement and
storage. Air quality regulators continue to look for ways to reduce emissions
from natural gas equipment, which could discourage future use of gas-burning
equipment by commercial and industrial customers.
Additional uncertainty comes from both California and federal plans to
restructure the electric industry. While these changes are not
expected to go into effect until 1998 at the earliest, they will affect SoCalGas
because electric utilities are its largest customers and among its staunchest
competitors.
Responding to these conditions, the PE Companies took steps to maintain the
profitability of their basic business, while identifying ways to move into new
energy related products and services within the utility service area
and beyond.
NEW ORGANIZATIONAL STRUCTURE
In the most dramatic step, the PE Companies were realigned into an organization
that concentrates its resources on its customers, allowing for a quicker
response to competitive threats and new business opportunities. The new
organization consists of three policy groups to oversee corporatewide functions
and five business units. This organizational structure groups activities,
functions and processes in order to serve customers better by delivering an
associated group of products and services. The business units are profit centers
and are held accountable for decisions affecting controllable costs, customer
revenues, level of service and quality and management of assets.
The business unit structure as it has been implemented also promotes
"enterprise thinking" among employees. It encourages them to see Pacific
Enterprises as a large organization with strengths and resources available
beyond their own business units, and to identify with the well-being of the PE
Companies as a whole.
The new organization also creates incentives for more entrepreneurial
behavior by tying management compensation more closely to performance goals.
PAGE 11 1995 Annual Report
FIVE NEW BUSINESS UNITS
The PE Companies are organized into five business units as follows:
- - ENERGY DISTRIBUTION SERVICES (EDS) serves the residential and small
commercial and industrial customers of SoCalGas. Its goal is to profitably
deliver gas and related services valued by these customers at the lowest
cost, while maintaining high levels of customer satisfaction and loyalty.
In this way, EDS seeks to maximize long-term cash flows and shareholder
return on its assets.
- - ENERGY TRANSPORTATION SERVICES (ETS) serves the large industrial, electric
generation and wholesale customers of SoCalGas. Its goal is to manage the
utility's transmission and storage assets profitably in a safe and reliable
manner, to maximize customer value and the return on invested capital, and to
be recognized as the low-cost provider of choice for natural gas
transmission, storage and related services.
Together EDS and ETS comprise Southern California Gas Company. With
separate business units serving different market segments, the utility is able
to meet competitive challenges in a more focused manner and respond to the
different needs of these customer groups.
- - ENERGY MANAGEMENT SERVICES (EMS) generates electricity from alternate energy
sources and conducts interstate pipeline operations. Its alternate energy
operations, under the Pacific Energy subsidiary, run power generating plants
that use alternate and renewable energy sources to generate electricity.
Pacific Energy's Central Plants Inc. subsidiary provides gas-powered central
heating and air conditioning to commercial complexes.
EMS' interstate pipeline operations, under Pacific Interstate Company,
deliver natural gas to SoCalGas from Canada and offshore California, supplying
29 percent of gas purchased by the utility in 1995.
EMS' goals are to profitably launch an array of related energy services,
not regulated by the CPUC, in California as well as in other domestic markets,
and to manage its portfolio of alternate energy projects, central plants and
pipeline assets to maximize earnings and cash flows.
- - NEW PRODUCT DEVELOPMENT (NPD) works with the other business units to lead the
development of new products and services. Through such collaborations its
goal is to provide professional quality product development skills across the
organization in order to enhance customer value and increase profits for the
PE Companies.
- - PACIFIC ENTERPRISES INTERNATIONAL (PEI) pursues equity investments in foreign
energy operations that present attractive prospects for earnings and growth.
In all such investments PEI will seek partners with proven local or
international experience.
PEI focuses on opportunities that fit with PE's proven skills and
expertise, such as acquisitions of existing distribution systems through
privatization efforts, development of new gas distribution systems, and
participation in transmission and in power generation projects. Areas of
interest include Latin America, Asia, the Pacific and Eastern Europe.
THREE NEW POLICY GROUPS
In addition to the five business units, three policy groups coordinate and
provide assistance in the areas of finance and planning, human resources and
public policy and law.
- - FINANCE AND PLANNING works with the business units to develop strategic and
financial plans, secures efficient financing for the PE Companies, assures
accurate financial records and timely reporting, maintains effective internal
controls and works with the Board of Directors to structure and maintain an
appropriate dividend policy.
- - HUMAN RESOURCES provides leadership to the PE Companies in developing and
implementing people strategies that support organizational and individual
success.
[PHOTO]
LEVERAGING CORE COMPETENCIES
The PE Companies are using core competencies to pursue new business
opportunities in both regulated and unregulated arenas. These endeavors may well
encompass insourcing services for other utilities, buying and selling natural
gas and electricity, or providing a variety of energy services, all for clients
anywhere in the United States.
[PHOTO]
FUNDAMENTAL STRATEGIES
PAGE 14 PACIFIC ENTERPRISES
- - PUBLIC POLICY and Law develops and assures consistency through the PE
Companies of long-term regulatory, political, legal and external
communication strategies in support of the PE Companies mission. In addition,
it supports each of the business units in these areas and monitors their
compliance with governmental, regulatory, legal and ethical requirements.
The realignment of the PE Companies will result in total annualized pre-tax
savings of $59 million, including a 21 percent reduction in headquarters costs.
Not all of these savings will benefit earnings, however, since about a third of
the dollars are related to lower capital expenditures, reduced research and
development and refundable ratepayer conservation programs at the utility.
CORE COMPETENCIES
The PE Companies are using core competencies, subject to regulatory restraints,
to pursue new business opportunities in regulated and unregulated arenas as
appropriate. Core competencies are those capabilities that the company possesses
at a level of expertise that translates into a competitive advantage.
In some cases business opportunities that offer significant growth
potential may lie beyond a core competence but involve activities in which the
PE Companies have a degree of expertise. In these cases PE will consider
acquisitions and/or partnerships or strategic alliances with other companies
that possess the required core competence.
To leverage its core competencies in 1995 Pacific Enterprises 1) began
identifying and evaluating international energy distribution and transmission
projects through its new international business unit; and 2) began identifying
and developing new energy-related products and services for either PE's
regulated or unregulated operations.
INTERNATIONAL OPPORTUNITIES
At the close of 1995 Pacific Enterprises International (PEI) had entered into a
memorandum of understanding for discussions and due diligence that could lead to
buying an interest in two utility holding companies located in Argentina. PEI
also had formed a partnership to pursue natural gas distribution opportunities
in Mexico. In both cases, the company has joined with partners that are
experienced at either the local or international level.
In Argentina the potential acquisition involves a 12.5 percent interest in
two utility holding companies that control natural gas utilities in central and
southern Argentina that collectively serve about 1 million customers with 625
million cubic feet of gas per day. PEI would take an active interest in their
management. The price was anticipated to be in the range of $50 million. A
decision whether to go ahead with the sale and a final determination of the
purchase price were expected as this report went to press.
In Mexico PEI announced in September that it had joined in partnership with
San Diego Gas & Electric Company and Proxima S.A. de C.V. to develop gas
distribution companies in the state of Baja California. The partnership notified
the Mexican Federal Government of its interest in building and operating a gas
distribution system for Mexicali. If the project went ahead PEI'S initial
investment would be less than $10 million. Others are competing for this
business, but the partnership is well positioned to provide the lowest cost
service to this market.
NEW PRODUCTS
The New Product Development (NPD) business unit teamed with SoCalGas' EDS
business unit to launch the pilot program for its first new product -- an
earthquake shutoff valve. Research indicated the seismic safety valve is a
product utility customers want, thus it is being made available through
SoCalGas.
By the end of 1995 the shutoff valve was being test-marketed to determine
the most effective approach for a system-wide launch.
Also by year-end NPD had received and evaluated 180 ideas, mostly from PE
Companies employees. Of these ideas, 27 merited further
PAGE 15 1995 ANNUAL REPORT
consideration, 20 were referred directly to a business unit and four moved ahead
with teams developing detailed business plans for test marketing and eventual
launch.
UTILITY PROFITABILITY
Within the two utility business units that were created, core competencies will
be focused more efficiently on customers, helping SoCalGas to be the low-cost
provider of products and services that customers value.
To help reduce costs, SoCalGas implemented "core process re-engineering,"
which reviews key operating processes to rethink and redesign these operations
so as to improve customer satisfaction and operating efficiencies. Similarly,
the competitive benchmarking program, which ensures that many utility functions
are competitive with outside providers, also has helped SoCalGas reduce
operating and maintenance expenses.
Since 1990 SoCalGas has reduced its workforce by 20 percent, mostly through
early retirements and attrition. Through the continued high dedication on the
part of employees, the utility has continued to provide safe and efficient
customer services and maintain high levels of customer satisfaction.
The utility also aggressively pursued lower gas purchase costs as part of
the pilot Gas Cost Incentive Mechanism that went into effect in mid-1994. Under
the three-year program, SoCalGas has an incentive to buy natural gas from
suppliers at less than a market-indexed price. If the utility achieves this, the
savings are shared by ratepayers and shareholders. If the price is higher than a
set "tolerance" band, shareholders must absorb half the extra cost. The
program's purchase costs were within the tolerance band for the first year.
SoCalGas continued its efforts to reduce the threat of customers bypassing
its system. The utility signed 23 transportation contracts with large
commercial, industrial, wholesale and electric generation customers,
representing 14 percent of its gas deliveries and providing the utility with an
important continuing revenue stream.
GROWTH OPPORTUNITIES
Reducing costs is one side of the equation. To realize growth potential, the PE
Companies also must offer energy services that customers value. One such effort
is TEEM (Total Energy Efficiency Management), a shareholder-funded program
launched in March 1995 to help commercial and industrial customers evaluate
their energy use and consider ways to increase energy efficiency and lower
costs.
In a small but growing market, a decision by the CPUC assured sufficient
ratepayer funds to meet the existing obligations of PE's natural gas vehicle
(NGV) program for the next six years. The program focuses on high-volume,
centrally fueled fleets where natural gas provides a competitive alternative to
gasoline. Currently there are 3,900 NGVS in SoCalGas' territory, adding an
estimated 450 million cubic feet of gas to the utility's annual natural gas
throughput.
To improve operating efficiencies, the utility will launch its Customer
Information System (CIS) in 1996. This state-of-the-art integrated computer
system will allow the utility to more efficiently manage all of its customer
transactions, from meter reading to billing to handling the roughly 10 million
customer calls it receives each year. Eventually CIS will allow customers to
select alternate payment options, such as paying by phone, ATM or computer, and
even automatic deductions from their bank accounts.
PERFORMANCE BASED REGULATION
With increased competition brought on by a changing energy marketplace,
operating under the traditional "cost of service" regulation will impair the
utility's ability to compete on a level playing field with non-regulated
entities. In response SoCalGas filed its far-reaching "performance based
regulation" (PBR) proposal with the CPUC last June.
The proposal, which points the utility in a market-oriented direction,
includes among its key elements a permanent reduction in base rates of
[PHOTO]
REALIGNING FOR SUCCESS
To remain competitive, PE concentrates its resources through a new business unit
structure that allows for more nimble responses to customer needs. Employees can
draw on the collective strengths of the PE Companies to pursue utility-related
opportunities anywhere in the world.
[PHOTO]
FUNDAMENTAL STRATEGIES
PAGE 18 PACIFIC ENTERPRISES
at least $41.6 million for all customers; an indexing measure that would limit
future rate increases to the inflation rate minus a productivity factor, and
rate refunds to core customers if service quality were to deteriorate.
PBR will present the utility with increased business risks as certain
protections against non-weather related fluctuations in gas deliveries to the
core market would be removed. On the upside, SoCalGas will be granted greater
flexibility in packaging and pricing services to respond to customers' needs.
PBR also will tie future utility earnings growth more closely to productivity
and new revenue sources and less to allowed investment in ratebase.
Unfortunately, intervenor requests before the CPUC will require the utility
to make an extensive supplemental filing that will delay PBR beyond
the utility's planned January 1, 1997 implementation date.
UNSUBSCRIBED CAPACITY
The PE Companies spearheaded an effort to resolve the issue of re-allocating
costs associated with unsubscribed capacity on two large interstate gas
pipelines serving California -- El Paso Natural Gas and Transwestern Pipeline.
The liability of this unsubscribed capacity potentially totaled more than $200
million annually, a burden likely to fall on the pipelines' firm customers,
including SoCalGas and their ratepayers.
A customer coalition led by SoCalGas reached agreement on a sharing
mechanism for these costs with Transwestern Pipeline and was negotiating an
agreement with El Paso as the year ended. The Transwestern settlement provides a
degree of rate certainty for SoCalGas customers over the coming decade.
NEXT STEPS
As the PE Companies move into 1996 and beyond, they will be guided by a set of
strategies that build on the accomplishments of 1995.
First, Pacific Enterprises will continue its transformation from a regional
utility holding company to a competitive provider of energy services. PE will be
even more customer-focused, delivering better services than its competitors and
at the lowest cost. The company will continue to build on established core
competencies and will develop or acquire those competencies needed to excel in
all markets in which it chooses to compete.
Second, Pacific Enterprises will remain fully committed to its utility
operations, supporting SoCalGas in providing outstanding service to its
customers. SoCalGas will continue to enhance its market position, cash flow and
profitability by providing customer value at a low, competitive cost. The
utility also will provide the source of competencies from which to launch
related domestic expansion.
Third, as the distinction between energy utility operations begins to blur,
Pacific Enterprises will build on initiatives to leverage natural gas skills in
California into broader energy services.
And fourth, Pacific Enterprises will continue to participate in
international gas infrastructure and market privatizations, focusing on
opportunities in Latin America, Asia, the Pacific, and Eastern Europe. In doing
so, the company will enter into these opportunities with experienced and
reputable international and local partners.
GLOSSARY OF TERMS & ABBREVIATIONS
PAGE 19 PACIFIC ENTERPRISES
AGGREGATOR One who provides a service of combining, or "aggregating," many
small-volume natural gas users into a single group in order to acquire gas
supplies for that group and/or to provide other services normally performed by
the utility.
BUSINESS UNIT A discrete grouping of business activities, functions and
processes aligned to provide an associated family of products and services
tailored to the needs of a specific customer market.
BYPASS A condition that occurs when a utility customer leaves the utility's
system to be served by a completely separate system and service provider.
BYPASS BY WIRE A condition that occurs when an electric utility buys
electricity from sources other than local generating facilities served by
SoCalGas.
CIS See Customer Information System.
CUSTOMER INFORMATION SYSTEM An integrated, state-of-the-art computerized
system that allows SoCalGas to manage its customer information, process a wide
range of customer record transactions, produce bills to core customers, process
all payments, follow-up delinquent accounts and report revenue.
COMPETITIVE BENCHMARKING A process of measuring the efficiency and cost-
effectiveness of an internal business process or function by comparing it with
the cost and quality of having the same process or function provided by an
external vendor.
COMPREHENSIVE SETTLEMENT A settlement negotiated by SoCalGas with interested
parties and approved by the CPUC in July 1994 that restructured certain long-
term gas supply contracts and resolved several regulatory matters affecting
SoCalGas. (Also referred to as Global Settlement.)
CORE CUSTOMERS SoCalGas customers who typically use less than 250,000 therms
per year.
CORE PROCESS RE-ENGINEERING A comprehensive evaluation of broad business
processes (i.e. revenue management or procurement and logistics) for purposes of
redesigning and implementing new processes that improve efficiency,
effectiveness and timeliness.
CPR See Core Process Re-engineering.
CPUC California Public Utilities Commission.
ELECTRIC INDUSTRY RESTRUCTURING A general term for efforts by state and
federal regulators to fundamentally change the way electric utilities are
regulated in order to provide consumers with more choice of service providers
and lower electric rates.
FERC Federal Energy Regulatory Commission.
GAS BROKER One who buys and sells natural gas on behalf of customers.
GAS AND POWER MARKETING A service that facilitates efficient matching of
buyers' and sellers' unique energy needs.
GAS COST INCENTIVE MECHANISM A 3-year pilot program approved by the CPUC as
part of the Comprehensive Settlement. The GCIM sets a standard for gas storage
operations and establishes a benchmark price, based on published industry
indices, for core gas purchases. It permits a 50-50 sharing between shareholders
and core customers of cost savings when SoCalGas buys natural gas at prices
below the benchmark. Shareholders are also at risk for half of any gas purchase
costs that exceed the benchmark plus a "tolerance band" of 4 percent.
GLOSSARY OF TERMS & ABBREVIATIONS
PAGE 20 PACIFIC ENTERPRISES
GCIM See Gas Cost Incentive Mechanism.
GPM See Gas and Power Marketing.
INTERVENOR A party with an interest in a specific proceeding before the CPUC.
LEV Low-emission vehicle.
MEGAWATT-HOUR A unit of measure of electrical energy that equals 1,000
kilowatt-hours; approximately 3.4 million BTUS.
NGV Natural gas vehicle.
NONCORE CUSTOMER SoCalGas customers who use more than 250,000 therms per
year.
PBR See Performance Based Regulation.
PERFORMANCE BASED REGULATION A form of utility regulation that relies on a
performance index system to track and reward utilities for efficiency in
providing safe, reliable and reasonably priced utility services to customers.
PBR usually gives the utility more flexibility in managing the business and
meeting changing customer needs in exchange for greater accountability for
providing effective results to customers.
PUHCA Public Utility Holding Company Act.
RATE BASE As determined by the CPUC, total dollars of net investment in a
utility's facilities required to provide service. For SoCalGas this includes
pipelines, storage facilities, supplies, materials, and working cash. Net
investment equals initial investment less accumulated depreciation.
RATE OF RETURN The rate of return, allowed or earned, on rate base. It
contains all elements of investors' return, including interest, preferred
dividends and return on common equity. Established by the CPUC.
RETURN ON EQUITY The rate of return allowed or earned on an equity
investment. Established by the CPUC for SoCalGas.
THERM A unit of heat energy equal to 100,000 BTUS, used in billing.
THROUGHPUT Total gas sales and transportation volumes moved through a
utility's pipeline system.
TOTAL RETURN TO SHAREHOLDERS Return measured by the calendar year change in
stock price plus the reinvested dividends paid for the year.
UNBUNDLING The subdividing of utility services into those to be included in a
utility's basic obligation to serve, and those to be excluded from the basic
obligation. Traditionally, utility services have been provided on a "bundled"
basis. Gas commodity and transportation costs, and the costs of other services
provided to customers were paid for through a single bundled rate, regardless of
what services were actually consumed. With unbundling the cost of component
services are separately stated. Customers can choose from whom they want to buy
the particular service and will only pay for those services they choose to
consume.
UNSUBSCRIBED CAPACITY That portion of a pipeline's capacity for which there
are no customers paying subscription fees for the rights to move their gas
supplies.
SOCALGAS SERVICE TERRITORY
PAGE 21 PACIFIC ENTERPRISES
[MAP]
Transmission Systems
AVERAGE THROUGHPUT - MILLIONS OF CUBIC FEET/DAY
SOCALGAS 3000
PG & E 2550
KERN/MOJAVE 850
TRANSMISSION INTERTIES WITH SOCALGAS SYSTEM
CITIES SERVICED
CITIES NOT SERVICED
NOTE: SOCALGAS SERVICE TERRITORY DOES NOT INCLUDE SAN DIEGO COUNTY OR THE CITY
OF LONG BEACH.
HOWEVER, BOTH ARE WHOLESALE CUSTOMERS OF SOCALGAS.
MANAGEMENT'S DISCUSSION & ANALYSIS
PAGE 22 PACIFIC ENTERPRISES
INTRODUCTION
This section includes management's analysis of operating results from 1993
through 1995, and is intended to provide additional information about Pacific
Enterprises' (the Company) capital resources, liquidity and financial
performance. This section also focuses on the major factors expected to
influence future operating results and discusses future investment and financing
plans. Management's Discussion and Analysis should be read in conjunction with
the Consolidated Financial Statements.
Pacific Enterprises is a Los Angeles-based utility holding company engaged
in supplying natural gas throughout most of southern and part of central
California. These operations are conducted through Southern California Gas
Company (SoCalGas), the nation's largest natural gas distribution utility,
serving 4.7 million meters in 535 cities and communities throughout a 23,000-
square-mile service territory with a population of approximately 17 million.
Through other subsidiaries, the Company is also engaged in interstate and
offshore natural gas transmission to serve its utility operations, in alternate
energy development and centralized heating and cooling for large building
complexes.
SoCalGas markets are separated into core customers and noncore customers.
Core customers consist of approximately 4.7 million customers (4.5 million
residential and 200,000 small commercial and industrial customers). The noncore
market consists of approximately 1,600 customers which include 8 utility
electric generation, 3 wholesale, and the remainder large commercial and
industrial customers. Most noncore customers procure their own gas supply rather
than purchase gas through the utility.
In 1995, the Company completed a realignment into five business units which
establishes a more flexible design to allow a more rapid response to competitive
forces. There are two business units at SoCalGas, one focusing on core
distribution customers and the other on large volume gas transportation
customers. The three other business
units focus on energy management services, new product development, and
international business opportunities.
CAPITAL RESOURCES AND LIQUIDITY
The Company's primary sources and uses of cash during the last three years are
summarized in the following condensed statement of cash flows:
SOURCES AND (USES) OF CASH
Year Ended December 31
-------------------------------------
(Dollars in millions) 1995 1994 1993
- -------------------------------------------------------------------------------------
Operating Activities $ 698 $ 255 $ 483
Capital Expenditures (240) (249) (331)
Financing Activities:
Long-Term Debt (207) 226 (679)
Short-Term Debt (44) 11 52
Issuance of
Common Stock 6 7 189
Redemption of
Preferred Stock (30) (40)
Common and
Preferred Dividends (121) (116) (65)
--------------------------------------
Total Financing Activities (396) 88 (503)
Other 2 41 71
-------------------------------------
Increase (Decrease) in Cash
and Cash Equivalents $ 64 $ 135 $ (280)
- --------------------------------------------------------------------------------------
- --------------------------------------------------------------------------------------
CASH FLOWS FROM OPERATING ACTIVITIES
The increase in cash flow from operating activities to $698 million in 1995 from
$255 million in 1994 is primarily due to a payment of $391 million for the
settlement of gas contract issues made in 1994.
The decrease in cash flow from operating activities of $228 million in 1994
from 1993 is primarily due to a payment for the settlement of gas contract
issues partially offset by an increase in collections of regulatory accounts
receivable. In addition, taxes paid in 1994 were higher due to the utilization
of net operating loss carryforwards in 1993.
There are a number of factors that impact the Company's cash flow from
operations. These include changes in operating expenses and return on equity. A
one percentage point change in return on equity impacts cash flow and net income
by approximately $13 million after taxes.
PAGE 23 PACIFIC ENTERPRISES
[GRAPH]
Allowed vs. Achieved
Return on Rate Base
(PERCENT)
Allowed
Achieved
91 92 93 94 95
10.79 10.49 9.99 9.22 9.67
10.94 11.01 10.27 9.74 10.84
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures primarily represent rate
base investment at SoCalGas. The table below summarizes capital expenditures by
utility plant classification:
CAPITAL EXPENDITURES Year Ended December 31
------------------------------------
(Dollars in millions) 1995 1994 1993
- -------------------------------------------------------------------------------------
SoCalGas:
Distribution $ 126 $ 129 $ 159
Transmission 19 24 54
Storage 19 22 33
Other 67 70 72
------------------------------------
Total SoCalGas 231 245 318
Other 9 4 13
------------------------------------
Total Expenditures $ 240 $ 249 $ 331
- -------------------------------------------------------------------------------------
- -------------------------------------------------------------------------------------
Capital expenditures for 1995 are $9 million lower than 1994 primarily the
result of reduced investing requirements for connecting new customers.
The decrease in expenditures in 1994 was due primarily to a $30 million
decrease in distribution main pipeline extensions as a result of fewer new
customer connections and a $30 million decrease in non-recurring transmission
projects such as the expansion of a compressor station and pipeline upgrades.
Capital expenditures are estimated to be $240 million in 1996. They will be
financed primarily by internally generated funds and will largely represent
investment in SoCalGas operations.
CASH FLOWS FROM FINANCING ACTIVITIES
In 1995, $396 million was used for financing activities. This is primarily the
result of a $30 million redemption of preferred stock, repayment of short and
long-term debt, and an increase in common dividends.
Cash flow provided by financing activities of $88 million in 1994 is due to
the issuance of long-term debt for financing a Comprehensive Settlement of gas
supply contracts and other regulatory issues (see Note 3 of Notes to
Consolidated Financial Statements - "Comprehensive Settlement of Regulatory
Issues") partially offset by the $40 million redemption of remarketed preferred
stock and an increase in common dividends.
The cash flow used for financing activities in 1993 of $503 million is
primarily due to the repayment of long-term debt with proceeds received from the
sale of discontinued operations and the sale of eight million shares of common
stock.
[GRAPH]
Capitalization Ratios
(PERCENT)
Capitalization
Debt
91 92 93 94 95
48 33 46 45 50
52 67 54 55 50
The decrease in the debt to capitalization ratio in 1995 to 50% from 55% in
1994 is primarily due to increases in common equity from 1995 income and the
repayment of debt.
During 1994 the debt to capitalization ratio remained relatively unchanged
from 1993. An increase in debt to finance the Comprehensive Settlement was
offset by 1994 net income and a $114 million adjustment to shareholders' equity
due to resolution of certain obligations related to discontinued operations (see
Note 2 of Notes to Consolidated Financial Statements).
During 1993 the Company completed the sale of discontinued operations and
eight million shares of common stock. The proceeds from the sales, including tax
benefits, together with cash provided by continuing operations, were used to
repay essentially all of the Parent Company's bank debt. As a result the debt to
capitalization ratio improved to 54% at the end of 1993 from 67% at the end of
1992.
The increase in the debt to capitalization ratio in 1992 of 15 percentage
points from 52% in 1991 is primarily due to losses from discontinued operations
and fair value adjustments charged to shareholders' equity as a result of the
quasi-reorganization.
MANAGEMENT'S DISCUSSION AND ANALYSIS (CONTINUED)
PAGE 24 PACIFIC ENTERPRISES
[GRAPH]
Annual Throughput Volumes
(BILLIONS OF CUBIC FEET)
Sold
Transported and Exchanged
91 92 93 94 95
1,047 1,001 965 1,020 937
CASH AND CASH EQUIVALENTS
Cash and cash equivalents are $351 million at December 31, 1995, of which $335
is at the Parent. This cash is available for investment in new energy-related
projects, redeeming preferred stock and debt and other corporate purposes.
The Company anticipates that cash required in 1996 for capital
expenditures, dividends and debt payments will be provided by cash generated
from operating activities and existing cash balances.
In addition to cash from ongoing operations, the Parent has available a
$300 million multi-year credit agreement requiring annual fees of .09%. SoCalGas
has a $650 million multi-year credit agreement requiring annual fees of .075%.
The interest rates on these lines vary and are derived from formulas based on
market rates and the companies' credit ratings. These multi-year credit
agreements expire in February, 2001. At December 31, 1995, all bank lines of
credit were unused. These lines of credit provide backing for SoCalGas'
commercial paper program.
SoCalGas has $415 million of commercial paper outstanding at December 31,
1995, including $265 million to finance the comprehensive settlement of gas
supply contracts and other regulatory issues, with the remainder financing
seasonal cash needs at SoCalGas.
PREFERRED STOCK REDEMPTION
The Company redeemed $30 million of preferred stock in 1995 and $40 million of
remarketed preferred stock in 1994. The Company plans to redeem up to $210
million of variable dividend rate preferred stock of the Parent and SoCalGas.
DIVIDENDS
The Company's goal is to increase the payout as a percentage of earnings over
time to be in line with the historical payout levels of our gas distribution
peers. The Company's 1995 payout stood at 63% while the historic payout level
for peers was in the range of 70 to 80%.
In 1995, the Company paid dividends of $111 million on common stock and $10
million on preferred stock for a total of $121 million. This compares to $116
million in 1994 and $65 million in 1993. The increase in 1995 was due to the
increase in the quarterly common stock dividend rate in the second quarter of
1995 partially offset by lower preferred dividends.
Dividends on common shares which had been suspended in 1992, were resumed in the
third quarter of 1993 at a quarterly rate of $.30 per share. The quarterly
dividend rate was increased to $.32 per share in the second quarter of 1994 and
to $.34 per share in the second quarter of 1995.
RESULTS OF CONSOLIDATED OPERATIONS
Net income for 1995 was $185 million, or $2.12 per share of common stock,
compared to net income of $172 million, or $1.95 per share in 1994 and net
income of $181 million, or $2.06 per share in 1993. The increase of $13 million
during 1995 is due primarily to the increase in the authorized rate of return on
common equity at SoCalGas from 11% in 1994 to 12% in 1995 and lower operating
expenses, which reflect savings from the Company's reduction in staffing levels
and other expense reductions. The decrease of $9 million in 1994 is due
primarily to a federal tax rate change benefit of $8 million recognized in 1993
and lower earnings at SoCalGas, partially offset by lower interest expense.
Although SoCalGas' authorized rate of return on common equity was reduced from
11.9% in 1993 to 11% in 1994, this reduction was substantially offset by
continued reductions in operating expenses, higher earnings from the noncore
market and the growth in rate base.
The weighted average number of shares of common stock outstanding increased
less than 1% to 82.3 million in 1995, following a 2% increase in 1994. The
increase in 1994 was due primarily to the full year's impact of eight million
shares issued in a second quarter public offering in 1993, partially offset by
the effect of the adoption in 1994 of the American Institute of Certified Public
Accountants' Statement of Position No. 93-6, "Employers' Accounting for Employee
Stock Ownership Plans" (SOP 93-6). For further discussion of SOP 93-6, see Note
12 of Notes to Consolidated Financial Statements.
Book value per share was $15.71 and $14.74 at December 31, 1995 and 1994,
respectively. The increase in book value per share of $.97 in 1995 is primarily
due to net income and an increase in shareholders' equity of $13 million for the
resolution of certain of the liabilities established in connection with the
Company's 1992 quasi-reorganization. For
PAGE 25 PACIFIC ENTERPRISES
[GRAPH]
SoCalGas
Employees Per 1,000 Meters
91 92 93 94 95
2.06 1.99 1.93 1.75 1.52
further discussion of the quasi-reorganization see Note 2 of Notes to
Consolidated Financial Statements.
SOCALGAS OPERATIONS
To fully understand the operations and financial results of SoCalGas it is
important to understand the ratemaking procedure that SoCalGas employs.
RATEMAKING PROCEDURES
SoCalGas is regulated by the California Public Utilities Commission (CPUC). It
is the responsibility of the CPUC to determine that utilities operate within the
best interests of the ratepayer, with the opportunity to earn a reasonable
return on investment.
Current ratemaking procedures are summarized below.
In a general rate case, the CPUC establishes a margin, which is the amount
of revenue authorized to be collected from customers to recover authorized
operating expenses (other than the cost of gas), depreciation, interest, taxes
and return on rate base. General rate cases are typically filed every three
years. On June 1, 1995 SoCalGas filed a "Performance Based Regulation" (PBR)
application with the CPUC which would replace the general rate case. For a
further discussion of PBR, see Factors Influencing Future Financial Performance
- - Performance Based Regulation.
The CPUC annually adjusts rates for years between general rate cases to
reflect the changes in rate base and the effects of inflation as adjusted by a
productivity improvement factor. Separate proceedings are held annually to
review SoCalGas' cost of capital, including return on common equity, interest
costs and changes in capital structure. The CPUC has authorized annual
allowances for 1996 for increases in operating and maintenance expenses to the
extent that the projected annual inflation rate exceeds 3%. In 1995, the CPUC
authorized allowances to the extent inflation exceeded 2%. For further
discussion of annual attrition allowances, see Note 3 of Notes to Consolidated
Financial Statements.
Biennial cost allocation proceedings (BCAP) adjust rates to reflect
variances in the cost of gas and customer demand from estimates adopted in a
general rate case. The mechanism substantially eliminates the effect on core
income of variances in core market demand and gas costs subject to the
limitations of the Gas Cost Incentive Mechanism and the Comprehensive
Settlement. For further discussion, see Note 3 of Notes to Consolidated
Financial Statements.
The CPUC approved a Gas Cost Incentive Mechanism (GCIM) for evaluating
SoCalGas' gas purchases. This mechanism compares SoCalGas' cost of gas with the
average market price of 30-day firm spot supplies delivered to the SoCalGas
service area and permits full recovery of all costs within a tolerance band
above that average. The cost of purchases above the tolerance band or savings
from purchases below the average market price are shared equally between
ratepayers and shareholders. For further discussion of GCIM, see Note 3 of Notes
to Consolidated Financial Statements.
1993-1995 FINANCIAL RESULTS
Under current utility ratemaking policies, the return that SoCalGas is
authorized to earn is the product of an authorized rate of return on rate base
and the amount of rate base. Rate base consists primarily of net investment in
utility plant. Thus, SoCalGas' earnings are affected by changes in the
authorized rate of return on rate base and the change in the authorized rate
base and by SoCalGas' ability to control expenses and investment in rate base
within the amounts authorized by the CPUC in setting rates. The Company refunds
or collects in the future the amounts by which certain defined costs vary from
the amounts authorized by the CPUC in the rate case or other regulatory
proceedings. Also, variations in core revenues from estimates adopted by the
CPUC in established rates are refunded or collected through the balancing
account mechanism. Thus, full balancing account treatment allows the Company to
fully recover amounts recorded as deferred costs or core revenue shortfalls
currently or in the future.
MANAGEMENT'S DISCUSSION AND ANALYSIS (CONTINUED)
PAGE 26 PACIFIC ENTERPRISES
[GRAPH]
Average Cost of Gas Purchased, Excluding Fixed Charges
(DOLLARS PER THOUSAND CUBIC FEET)
91 92 93 94 95
2.40 2.24 2.21 1.68 1.42
Key financial and operating data for SoCalGas are highlighted in the table
below.
Year Ended December 31
----------------------
(Dollars in millions) 1995 1994 1993
- -------------------------------------------------------------------------------------
Operating revenues $ 2,279 $ 2,587 $ 2,811
Cost of gas $ 737 $ 992 $ 1,187
Operating expenses $ 760 $ 827 $ 868
Net income (after
preferred dividends) $ 203 $ 180 $ 184
Authorized return on
rate base 9.67% 9.22% 9.99%
Authorized return on
common equity 12.00% 11.00% 11.90%
Weighted average
rate base $ 2,766 $ 2,862 $ 2,769
(Decline) growth in
weighted average rate
base over prior period (3.4)% 3.4% 1.8%
- -------------------------------------------------------------------------------------
- -------------------------------------------------------------------------------------
SoCalGas' operating revenues decreased $308 million in 1995. The decrease
is primarily due to a reduction in the average unit cost of gas and a decrease
in noncore transportation volumes. SoCalGas' cost of gas distributed decreased
$255 million in 1995 due to lower volumes of gas purchased for customers and a
decrease in the average unit cost of gas. The decrease in transportation volumes
was primarily in the utility electric generation market. This was due to an
abundance of less expensive hydro-electricity resulting from high levels of
precipitation last winter. The decrease in operating revenues of $224 million in
1994 reflects a reduction in authorized gas margin and the average unit cost of
gas partially offset by the growth in rate base and an increase in noncore
volumes transported. SoCalGas' cost of gas distributed decreased $195 million in
1994. The average commodity cost of gas purchased by SoCalGas, excluding fixed
charges, for 1995 was $1.42 per thousand cubic feet, compared to $1.68 per
thousand cubic feet in 1994 and $2.21 per thousand cubic feet in 1993.
SoCalGas' operating expenses decreased $67 million in 1995. The decrease
primarily reflects savings from cost reduction efforts in 1995 and nonrecurring
expenses in 1994. Operating costs for 1994 included expenses resulting from the
January 1994 earthquake and expenses related to a discontinued capital project.
The decrease of $41 million in 1994 is primarily due to aggressive reductions in
operating expenses partially offset by the nonrecurring expenses discussed
above.
SoCalGas has achieved or exceeded the rate of return on rate base
authorized by the CPUC for 13 consecutive years. In 1995, SoCalGas achieved a
10.84% return on rate base, compared to a 9.67% authorized return, and a 13.89%
return on equity, compared to a 12% authorized return. The improved returns were
primarily due to lower operating costs as a result of reduced staffing levels
and other cost reduction efforts.
In 1994, SoCalGas achieved a 9.74% return on rate base, compared to a 9.22%
authorized return, and a 12.33% return on equity, compared to an 11% authorized
return. The improved returns were primarily due to more efficient operations
through reductions in operating expenses, higher noncore earnings and a
conservation award.
SoCalGas plans to continue efforts to control costs in 1996. In 1996,
SoCalGas is authorized to earn 9.42% return on rate base and 11.6% on common
equity. Rate base is expected to decline slightly from the level in 1995.
OPERATING RESULTS
The table on the following page summarizes the components of SoCalGas'
throughput and rates charged to customers for the past three years. Beginning
January 1, 1994, rates included the ratepayer portion of the Comprehensive
Settlement (See Note 3 of Notes to Consolidated Financial Statements). The
amount included in rates for 1995 was $84 million and in 1994 was $119 million.
Although the revenues from transportation throughput are less than for gas
sales, SoCalGas generally earns the same margin whether it buys the gas and
sells it to the customer or transports gas already owned by the customer. For
1996, approximately 89% of total margin authorized is contributed by the core
market (residential and
PAGE 27 PACIFIC ENTERPRISES
[GRAPH]
SoCalGas
1996 Authorized Margin
Core Market 89%
Noncore Market 11%
(Dollars in millions, Gas Sales Transportation and Exchange Total
------------------------- --------------------------- -------------------------
volume in billion cubic feet) Throughput Revenue Throughput Revenue Throughput Revenue
- -----------------------------------------------------------------------------------------------------------------------------
1995:
Residential 237 $1,547 2 $ 7 239 $1,554
Commercial/Industrial 97 546 267 206 364 752
Utility Electric Generation 205 104 205 104
Wholesale 4 7 125 55 129 62
---------------------------------------------------------------------------------
Total in Rates 338 $2,100 599 $ 372 937 2,472
Balancing and Other (193)
------
Total Operating Revenues $2,279
- -----------------------------------------------------------------------------------------------------------------------------
1994:
Residential 254 $1,704 2 $ 9 256 $1,713
Commercial/Industrial 100 592 258 207 358 799
Utility Electric Generation 260 118 260 118
Wholesale 8 21 138 77 146 98
---------------------------------------------------------------------------------
Total in Rates 362 $2,317 658 $ 411 1,020 2,728
Balancing and Other (141)
------
Total Operating Revenues $2,587
- -----------------------------------------------------------------------------------------------------------------------------
1993:
Residential 244 $1,641 4 $ 12 248 $1,653
Commercial/Industrial 97 610 259 247 356 857
Utility Electric Generation 4 213 143 213 147
Wholesale 11 27 137 90 148 117
---------------------------------------------------------------------------------
Total in Rates 352 $2,282 613 $ 492 965 2,774
Balancing and Other 37
------
Total Operating Revenues $2,811
- -----------------------------------------------------------------------------------------------------------------------------
- -----------------------------------------------------------------------------------------------------------------------------
smaller commercial and industrial customers), with 11% contributed by the
noncore market.
Throughput, the total gas sales and transportation volumes moved through
SoCalGas' system, decreased in 1995 as a result of lower demands, primarily by
utility electric generators. This was as a result of an abundance of inexpensive
hydro-electricity. The increase in throughput in 1994 from 1993 levels was the
result of greater weather-related demand in noncore volumes, primarily utility
electric generation.
FACTORS INFLUENCING FUTURE FINANCIAL PERFORMANCE
Performance of the Company in the near future will primarily depend on the
results of SoCalGas. Because of the ratemaking and regulatory process as well as
the changing energy marketplace, there are several factors that will influence
future financial performance. These factors are summarized below.
Under current ratemaking policies, future SoCalGas net income and cash flow
will be determined primarily by the allowed rate of return on common equity,
changes to authorized rate base, noncore market pricing, the variance in gas
volumes delivered to noncore customers from CPUC-adopted forecast deliveries and
the ability of management to control expenses and investment in line with the
amounts authorized by the CPUC to be collected in rates.
Future regulatory restructurings (including the PBR proposal from
SoCalGas), increased competitiveness in the industry (including the continuing
threat of customers bypassing SoCalGas' system and obtaining service directly
from interstate pipelines), and electric industry restructuring could also
affect SoCalGas' future performance.
The following detailed discussion addresses each of the major factors
expected to influence future financial performance:
- - ALLOWED RATE OF RETURN SoCalGas' earnings for 1996 will be affected by a
decrease in the authorized rate of return on common equity. For 1996,
SoCalGas is authorized to earn a rate of return on rate base of 9.42% and a
rate of return on common equity of 11.6%, compared to 9.67% and 12%,
respectively, in 1995. A change in return on equity of one percentage point
impacts net income by approximately $13 million. The CPUC has also
authorized an increase in the equity component of SoCalGas' capital
structure
MANAGEMENT'S DISCUSSION AND ANALYSIS (CONTINUED)
PAGE 28 PACIFIC ENTERPRISES
[GRAPH]
Annual Cost of Appliance Operation
Gas vs. Electric
(Dollars)
Space Water Clothes Cooking
Gas 270 145 47 32
Electric 838 523 124 113
to 47.4% in 1996 from 47.0% in 1995. The 40 basis point increase in the
equity component should add between $1 million to $2 million to earnings.
Rate base is expected to decline slightly from the level in 1995.
- - NONCORE BYPASS SoCalGas' throughput to enhanced oil recovery (EOR)
customers in the Kern County area has decreased significantly because of
the bypass of SoCalGas' system by competing interstate pipelines. The
decrease in revenues from EOR customers is subject to full balancing
account treatment, except for a 5% incentive to SoCalGas, and therefore,
does not have a material impact on SoCalGas' earnings.
Bypass of other markets may also occur, and SoCalGas is fully at risk
for lost non-EOR noncore volumes due to bypass. SoCalGas is continuing to
reduce its costs to maintain low cost competitiveness to retain
transportation customers. Also, significant additional bypass would require
construction of additional facilities by competing pipelines.
- - NONCORE PRICING To respond to bypass, SoCalGas has received authorization
from the CPUC for expedited review of long-term gas transportation service
contracts with some noncore customers at lower than tariff rates. In
addition the CPUC approved changes in the methodology that eliminates
subsidization of core customer rates by noncore customers. This allocation
flexibility, together with negotiating authority, has enabled SoCalGas to
better compete with new interstate pipelines for noncore customers.
- - NONCORE THROUGHPUT SoCalGas' earnings may be adversely impacted if gas
throughput to its noncore customers varies from estimates adopted by the
CPUC in establishing rates. There is a continuing risk that an unfavorable
variance in noncore volumes can result from external factors such as
weather, electric deregulation, the increased use of hydroelectric power,
competing pipeline bypass of SoCalGas' system and a downturn in general
economic conditions. In addition many noncore customers are especially
sensitive to the price relationship between natural gas and alternate
fuels, as they are capable of readily switching from one fuel to another,
subject to air quality regulations. SoCalGas is at risk for the lost
revenue.
Through July 31, 1999 any favorable earnings effect of higher revenues
resulting from higher throughput to noncore customers has been eliminated
as a result of the Comprehensive Settlement described in Note 3 of Notes to
the Consolidated Financial Statements.
- - EXCESS INTERSTATE PIPELINE CAPACITY Existing interstate pipeline capacity
into California exceeds current demand by over 1 billion cubic feet per
day. Up to 2 billion cubic feet per day of capacity on the El Paso and
Transwestern interstate pipeline systems, representing over $175 million
and $55 million, respectively, of annual reservation charges to pipeline
customers may be relinquished within the next few years. Some of this
capacity may not be resubscribed. Current Federal Energy Regulatory
Commission (FERC) regulation could permit the cost of unsubscribed capacity
to be allocated to remaining firm service customers, including SoCalGas.
Under existing regulation in California, SoCalGas would have the
opportunity to include its portion of any such reallocated costs in its
rates.
The FERC has approved a settlement with Transwestern which calls for
firm customers, including SoCalGas, to subsidize unsubscribed pipeline
costs for a five year period with Transwestern assuming full responsibility
after that time. Negotiations are continuing with El Paso and a settlement
is expected to be filed with the FERC in the first quarter of 1996.
- - MANAGEMENT CONTROL OF EXPENSES AND INVESTMENT Over the past 13 years,
management has been able to control operating expenses and investment
within the amounts authorized to be collected in rates and intends to
continue to do so.
- - PERFORMANCE BASED REGULATION SoCalGas has filed a PBR application with the
CPUC to replace the general rate case and certain other traditional
regulatory proceedings. PBR, if approved, would allow SoCalGas to be more
responsive to consumer interests and compete more effectively in
MANAGEMENT'S DISCUSSION AND ANALYSIS (CONTINUED)
PAGE 29 PACIFIC ENTERPRISES
[GRAPH]
New Meter Sets Per Year
(THOUSANDS)
91 92 93 94 95
75.8 55.8 47.0 43.4 40.9
contestable markets. Key elements of this proposal include a permanent reduction
in base rates of $42 million, an indexing measure that would limit future rate
increases to the inflation rate less a productivity factor and rate refunds to
customers if service quality were to deteriorate. This new approach would
maintain cost based rates but would link financial performance with changes in
productivity. Although PBR could result in increased earnings volatility,
SoCalGas would have the opportunity to improve financial performance to the
extent it was able to reduce expenses, increase energy deliveries and generate
profits from new products and services.
Under the PBR proposal, SoCalGas would be at risk for certain changes in
interest rates and cost of capital, changes in core volumes not caused by
weather, and achievement of productivity improvements. The CPUC's process for
approval of PBR has been delayed pending determination of additional information
needed to establish the starting base cost of service. An agreement with several
interested parties has been reached under which SoCalGas will provide a
substantial portion of the supporting documentation that would be required for a
general rate case proceeding. This additional step will delay implementation
beyond the proposed January 1, 1997 starting date.
- - ELECTRIC INDUSTRY RESTRUCTURING Demand for natural gas by electric
generation customers is sensitive to the price and availability of electric
power generated in other areas and purchased by these electric generation
customers.
On December 20, 1995, the CPUC issued a final decision to restructure
California electric utility regulation. Implementation of portions of the
plan are expected to need state legislative or federal administrative
approval. The CPUC's decision has no immediate effect on SoCalGas'
operations. However, SoCalGas is continuing to evaluate the decision
because future volumes of natural gas it transports for electric utilities
may be adversely affected by increased use of electricity generated by out-
of-state producers. The electric industry restructuring also may result in
a reduction of electric rates to core customers, but it is unlikely to
overcome the entire cost advantage of natural gas for existing uses.
- - ENVIRONMENTAL MATTERS SoCalGas' operations and those of its customers are
affected by a growing number of environmental laws and regulations. These
laws and regulations affect current operations as well as future expansion.
Increasingly complex administrative and reporting requirements of
environmental organizations applicable to commercial and industrial
customers utilizing natural gas are not generally required by those using
electricity. However, anticipated advancement in natural gas technologies
will enable gas equipment to remain competitive with alternate energy
sources. Environmental laws also require clean up of facilities no longer
in use. Because of current and expected rate recovery, SoCalGas believes
that compliance with these laws will not have a significant impact on its
financial statements. For further discussion of environmental and
regulatory matters, see Note 5 of Notes to Consolidated Financial
Statements.
- - UNION CONTRACT Most field, clerical and technical employees of SoCalGas
are represented by the Utility Workers' Union of America or the
International Chemical Workers' Union. A contract with these unions
relating to benefits expired in 1995 and a contract covering wages, hours
and working conditions will expire on March 31, 1996. Negotiations related
to new contracts are ongoing.
- - CALIFORNIA ECONOMY Growth in SoCalGas markets is largely dependent on the
health and expansion of the California economy. While California has
undergone a recession in recent years current economic forecasts indicate
the state will experience a higher growth in jobs than the rest of the
country.
ENERGY MANAGEMENT SERVICES
Energy Management Services (EMS) consists primarily of Pacific Interstate
Company and Pacific Energy.
Pacific Interstate Company, an interstate pipeline subsidiary which is
regulated by the FERC, purchases natural gas from producers in Canada and from
federal waters offshore California and transports it for resale to SoCalGas.
During 1995, these deliveries from the interstate pipeline subsidiaries
accounted for approximately 29% of the total volume of gas purchased by SoCalGas
MANAGEMENT'S DISCUSSION & ANALYSIS (CONTINUED)
PAGE 30 PACIFIC ENTERPRISES
[GRAPH]
PacificEnterprises
Capital Expenditures
(MILLIONS OF DOLLARS)
91 92 93 94 95
335 329 331 249 240
and approximately 10% of SoCalGas' total throughput. The gas is purchased under
long-term contracts which were restructured in conjunction with the
Comprehensive Settlement.
Pacific Energy develops and operates alternate energy facilities and
operates centralized heating and cooling plants.
Net income of EMS was $8 million in 1995 compared to $10 million in 1994.
The decrease was primarily due to a $4 million nonrecurring charge for certain
power sales contract restructuring issues partially offset by lower general and
administrative expenses.
PACIFIC ENTERPRISES INTERNATIONAL
Pacific Enterprises International (PEI) was established in late 1994 to
participate in the international gas infrastructure market. Net costs for the
year were $2 million.
In January 1996, PEI entered into a non-binding memorandum of understanding
which may result in acquisition of a 12.5% interest in two utility holding
companies that control natural gas distribution utilities in Argentina. The
acquisition price is anticipated to be approximately $50 million.
These utilities in central and southern Argentina deliver about 625 million
cubic feet of gas per day to one million customers. PEI expects to have a role
in managing the utility operations. A decision on the acquisition will be made
by the end of the first quarter of 1996.
PEI also has formed a partnership with San Diego Gas & Electric Co. and
Proxima, S.A. de C.V. to build and operate natural gas distribution networks in
Mexico.
The partnership's first project, if awarded the franchise by the Mexican
government, would be to distribute gas to the City of Mexicali in Baja
California. This proposed distribution network would have the capacity to
deliver 80 million cubic feet of gas per day. If approved by the government,
licensing would take approximately six months and actual construction of the
pipeline and facilities would require another six months. pei would initially
invest less than $10 million in this project.
Other international projects are currently under evaluation.
PARENT COMPANY AND OTHER
The Parent is a holding company which provides services to its subsidiaries. The
net losses in 1995, 1994 and 1993 were $25 million, $17 million and $14 million,
respectively, including interest expense. Also included is $1 million of costs
for the New Product Development business unit which was established in 1995 to
identify and implement new products and services.
OTHER INCOME, INTEREST EXPENSE AND INCOME TAXES
OTHER INCOME
Other income was $34 million, $38 million and $24 million in 1995, 1994 and
1993, respectively. Other income primarily consists of interest income on
regulatory accounts receivable balances and interest income from short-term
investments. The increases from 1993 are primarily due to a higher level of
short-term investments.
INTEREST EXPENSE
Interest expense was $108 million, $128 million and $135 million in 1995, 1994
and 1993, respectively. Interest expense in 1995 and 1994 was reduced from the
1993 level as a result of repayment of nonutility debt and refinancing of
SoCalGas debt at lower interest rates. The Company had two interest rate swap
agreements which effectively set $200 million of variable rate debt to fixed
rates and expired in September, 1995 (See Note 8 of Notes to Consolidated
Financial Statements).
INCOME TAXES
Income tax expense was $129 million, $139 million and $126 million in 1995, 1994
and 1993, respectively. The decrease of $10 million in 1995 is primarily due to
higher capitalized software costs which are deductible for tax purposes. The
increase of $13 million in 1994 was primarily due to the one time $8 million
benefit from a 1993 tax rate change.
CONSOLIDATED STATEMENT OF INCOME
PAGE 31 PACIFIC ENTERPRISES
Year Ended December 31
----------------------
(Dollars are in millions, except per-share amounts) 1995 1994 1993
- ----------------------------------------------------------------------------------------------------
REVENUES AND OTHER INCOME
Operating Revenues $ 2,343 $ 2,664 $ 2,899
Other 34 38 24
--------------------------------------
Total 2,377 2,702 2,923
--------------------------------------
EXPENSES
Cost of Gas Distributed 682 924 1,086
Operating Expenses 920 977 1,029
Depreciation and Amortization 243 239 243
Franchise Payments and Other Taxes 98 113 113
Preferred Dividends of a Subsidiary 12 10 10
--------------------------------------
Total 1,955 2,263 2,481
--------------------------------------
Income from Operations Before Interest and Taxes 422 439 442
Interest 108 128 135
--------------------------------------
Income from Operations Before Income Taxes 314 311 307
Income Taxes 129 139 126
--------------------------------------
Net Income 185 172 181
Dividends on Preferred Stock 10 12 15
--------------------------------------
Net Income Applicable to Common Stock $ 175 $ 160 $ 166
--------------------------------------
--------------------------------------
Net Income Per Share of Common Stock $ 2.12 $ 1.95 $ 2.06
--------------------------------------
--------------------------------------
Common Dividends Declared Per Share $ 1.34 $ 1.26 $ .60
--------------------------------------
--------------------------------------
WEIGHTED AVERAGE NUMBER OF SHARES OF
COMMON STOCK OUTSTANDING (IN THOUSANDS) 82,265 81,939 80,472
- ----------------------------------------------------------------------------------------------------
- ----------------------------------------------------------------------------------------------------
SEE NOTES TO CONSOLIDATED FINANCIAL STATEMENTS.
CONSOLIDATED BALANCE SHEET
PAGE 32 PACIFIC ENTERPRISES
December 31
-------------------
(Dollars in Millions) 1995 1994
- ----------------------------------------------------------------------------------------------------
ASSETS
Property, Plant and Equipment $ 5,909 $ 5,710
Less accumulated depreciation and amortization 2,627 2,430
-----------------------
Total property, plant and equipment, net 3,282 3,280
-----------------------
Current Assets:
Cash and cash equivalents 351 287
Accounts receivable - trade (less allowance for doubtful receivables
of $16 in 1995 and $13 in 1994) 356 500
Accounts and notes receivable-other 67 37
Income taxes receivable 18
Deferred income taxes 17
Gas in storage 55 64
Other inventories 22 35
Regulatory accounts receivable-net 246 360
Prepaid expenses 38 40
-----------------------
Total current assets 1,170 1,323
-----------------------
Other Investments 53 51
Other Receivables 18 30
Regulatory Assets 645 707
Other Assets 91 54
-----------------------
Total assets $ 5,259 $ 5,445
- ----------------------------------------------------------------------------------------------------
- ----------------------------------------------------------------------------------------------------
SEE NOTES TO CONSOLIDATED FINANCIAL STATEMENTS.
- --------------------------------------------------------------------------------
CONSOLIDATED BALANCE SHEET
PAGE 33 PACIFIC ENTERPRISES
December 31
----------------------
(Dollars in Millions) 1995 1994
- ------------------------------------------------------------------------------------------
CAPITALIZATION
Shareholders' Equity:
Capital stock:
Remarketed Preferred, Series A $ 108 $ 108
Preferred 80 110
Common 1,111 1,092
----------------------
Total capital stock 1,299 1,310
Retained earnings, after elimination of accumulated deficit
of $452 million against common stock at
December 31, 1992 as part
of the quasi-reorganization 236 172
Less deferred compensation relating to Employee
Stock Ownership Plan (52) (54)
----------------------
Total shareholders' equity 1,483 1,428
Preferred Stocks of a Subsidiary 195 195
Long-Term Debt 1,241 1,420
Debt of Employee Stock Ownership Plan 130 130
----------------------
Total capitalization 3,049 3,173
----------------------
LIABILITIES
Current Liabilities:
Short-term debt 234 278
Accounts payable-trade 177 235
Accounts payable-other 299 234
Accrued income taxes 12
Deferred income taxes 34
Other taxes payable 47 53
Long-term debt due within one year 100 128
Accrued interest 44 42
Other 64 130
----------------------
Total current liabilities 965 1,146
----------------------
Long-Term Liabilities 232 255
Customer Advances for Construction 47 44
Postretirement Benefits Other than Pensions 235 245
Deferred Income Taxes 246 157
Deferred Investment Tax Credits 67 70
Other Deferred Credits 418 355
Commitments and Contingent Liabilities (Note 5)
----------------------
Total capitalization and liabilities $ 5,259 $ 5,445
- ------------------------------------------------------------------------------------------
SEE NOTES TO CONSOLIDATED FINANCIAL STATEMENTS.
STATEMENT OF CONSOLIDATED CASH FLOWS
PAGE 34 PACIFIC ENTERPRISES
Year Ended December 31
-------------------------------------
(Dollars in Millions) 1995 1994 1993
- ----------------------------------------------------------------------------------------------------
CASH FLOWS FROM OPERATING ACTIVITIES
Income from Continuing Operations $ 185 $ 172 $ 181
Adjustments to Reconcile Income from Continuing
Operations to Net Cash Provided by (Used in)
Operating Activities:
Depreciation and amortization 243 239 243
Deferred income taxes 71 (37) 95
Other-net (3) (31) (12)
Net change in other working capital components 202 (153) (130)
------------------------------------
Total from continuing operations 698 190 377
Changes in operating assets and liabilities
of discontinued operations 65 106
------------------------------------
Net cash provided by operating activities 698 255 483
------------------------------------
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for Property, Plant and Equipment (240) (249) (331)
Increase in Other Investments (2) (3)
------------------------------------
Total capital expenditures and other investments (242) (249) (334)
Proceeds from Disposition of Properties 2 1
(Increase) Decrease in Other Receivables, Regulatory
Assets and Other Assets 2 40 (28)
Net Investing Activities Relating to Discontinued Operations 102
------------------------------------
Net cash used in investing activities (238) (208) (260)
------------------------------------
CASH FLOWS FROM FINANCING ACTIVITIES
Sale of Common Stock 6 7 189
Redemption of Preferred Stock (30) (40)
Sale of Preferred Stock of a Subsidiary 75
Redemption of Preferred Stock of a Subsidiary (75)
Increase in Long-Term Debt 246 931
Decrease in Long-Term Debt (207) (20) (1,610)
Increase (Decrease) in Short-Term Debt (44) 11 52
Common and Preferred Dividends (121) (116) (65)
------------------------------------
Net cash provided by (used in) financing activities (396) 88 (503)
------------------------------------
Increase (Decrease) in Cash and Cash Equivalents 64 135 (280)
Cash and Cash Equivalents, January 1 287 152 432
------------------------------------
Cash and Cash Equivalents, December 31 $ 351 $ 287 $ 152
- ----------------------------------------------------------------------------------------------------
- ----------------------------------------------------------------------------------------------------
SEE NOTES TO CONSOLIDATED FINANCIAL STATEMENTS.
STATEMENT OF CONSOLIDATED CASH FLOWS
PAGE 35 PACIFIC ENTERPRISES
Year Ended December 31
-------------------------------------
(Dollars in Millions) 1995 1994 1993
- ----------------------------------------------------------------------------------------------------
CHANGES IN OTHER WORKING CAPITAL COMPONENTS
(Excluding cash and cash equivalents, short-term debt
and long-term debt due within one year)
Current Assets:
Receivables $ 114 $ (18) $ 5
Inventories 22 (13) (17)
Regulatory accounts receivable 198 237 (113)
Other 2 (10) 32
------------------------------------
Total 336 196 (93)
------------------------------------
Current Liabilities:
Accounts payable 7 (454) 38
Accrued income taxes (30) 32 (49)
Deferred income taxes (42) 46 (23)
Other taxes payable (6) 1 (8)
Other (63) 26 5
------------------------------------
Total (134) (349) (37)
------------------------------------
Net change in other working capital components $ 202 $ (153) $ (130)
------------------------------------
------------------------------------
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Cash Paid (Refunded) During the Year for:
Interest (net of amount capitalized) $ 101 $ 130 $ 131
Income taxes $ 129 $ 98 $ (25)
- ----------------------------------------------------------------------------------------------------
- ----------------------------------------------------------------------------------------------------
SEE NOTES TO CONSOLIDATED FINANCIAL STATEMENTS.
STATEMENT OF CONSOLIDATED SHAREHOLDERS' EQUITY
PAGE 36 PACIFIC ENTERPRISES
Deferred
compensation
Years Ended December 31, Preferred Stock Common Stock relating to
1995, 1994 and 1993 ------------------------ ------------------------ Employee Stock Total
Number of No par Number of No par Retained Ownership Plan shareholders'
(In millions, except share shares value shares value Earnings (ESOP) equity
amounts)
- ----------------------------------------------------------------------------------------------------------------------------------
BALANCES AT DECEMBER 31, 1992 1,101,903 $258 75,289,828 $ 859 $(148) $ 969
Net Income $181 181
Cash Dividends Declared:
Preferred Stock (15) (15)
Common Stock (50) (50)
Common Stock Sold 8,904,387 189 189
Redemption of Preferred Stock (50)
Decrease in Deferred
Compensation Relating to esop 10 10
- ----------------------------------------------------------------------------------------------------------------------------------
BALANCES AT DECEMBER 31, 1993 1,101,853 258 84,194,215 1,048 116 (138) 1,284
Net Income 172 172
Cash Dividends Declared:
Preferred Stock (12) (12)
Common Stock (104) (104)
Common Stock Sold 337,577 7 7
Quasi-Reorganization
Adjustment 37 77 114
Redemption of Remarketed
Preferred Stock (400) (40) (40)
Adoption of SOP 93-6 (2,575,690)
Common Stock Released from esop 155,161 7 7
- ----------------------------------------------------------------------------------------------------------------------------------
BALANCES AT DECEMBER 31, 1994 1,101,453 218 82,111,263 1,092 172 (54) 1,428
Net Income 185 185
Cash Dividends Declared:
Preferred Stock (10) (10)
Common Stock (111) (111)
Common Stock Sold 232,310 6 6
Quasi-Reorganization
Adjustment 13 13
Redemption of Preferred Stock (300,100) (30) (30)
Common Stock Released from esop 103,098 2 2
- ----------------------------------------------------------------------------------------------------------------------------------
BALANCES AT DECEMBER 31, 1995 801,353 $188 82,446,671 $1,111 $236 $ (52) $1,483
- ----------------------------------------------------------------------------------------------------------------------------------
- ----------------------------------------------------------------------------------------------------------------------------------
THE NUMBER OF SHARES OF COMMON STOCK AUTHORIZED AT DECEMBER 31, 1995 AND 1994 IS
600,000,000. THE NUMBER OF SHARES OF PREFERRED STOCK AND CLASS A PREFERRED STOCK
AUTHORIZED AND OUTSTANDING AT DECEMBER 31, 1995 AND 1994 IS SET FORTH IN NOTE 11
OF NOTES TO CONSOLIDATED FINANCIAL STATEMENTS.
SEE NOTES TO CONSOLIDATED FINANCIAL STATEMENTS.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
PAGE 37 PACIFIC ENTERPRISES
1. SUMMARY OF SIGNIFICANT
ACCOUNTING POLICIES
PRINCIPLES OF CONSOLIDATION
The consolidated financial statements include the accounts of all subsidiaries
of Pacific Enterprises (the Company). Investments in 50-percent-or-less owned
joint ventures and partnerships are accounted for by the equity method or cost
method, as appropriate.
RECLASSIFICATIONS
Certain changes in account classification have been made in the prior years'
consolidated financial statements to conform to the 1995 financial statement
presentation.
REGULATION
In conformity with generally accepted accounting principles (GAAP), Southern
California Gas Company's (SoCalGas) accounting policies reflect the financial
effects of rate regulation authorized by the California Public Utilities
Commission (CPUC). In conformity with GAAP, interstate natural gas transmission
subsidiaries follow accounting policies authorized by the Federal Energy
Regulatory Commission (FERC). The regulated subsidiaries apply the provisions of
Statement of Financial Accounting Standards No. 71, "Accounting for the Effects
of Certain Types of Regulation." This statement requires cost-based rate
regulated entities that meet certain criteria to reflect the authorized recovery
of costs due to regulatory decisions in their financial statements. The Company
records Regulatory Assets, which represent assets that are being recovered
through customer rates or are probable of being recovered through customer
rates. As of December 31, 1995, the Company had $645 million of regulatory
assets which included the following: costs of reacquiring debt - $52 million;
postretirement benefit costs (see Note 12) - $219 million; Comprehensive
Settlement costs (see Note 3) - $175 million; deferred income taxes (see Note 4)
- - $109 million; and other costs - $90 million.
Maintenance of the regulatory accounts and regulatory accounts receivable
represents the only difference in the application of GAAP for the utility verses
non-regulated entities.
REGULATORY ACCOUNTS RECEIVABLE - NET
Authorized regulatory balancing accounts are maintained to accumulate
undercollections and overcollections from the revenue and cost estimates adopted
by the CPUC in setting rates. SoCalGas makes periodic filings with the CPUC to
adjust future gas rates to account for such variances.
INVENTORIES
Gas in storage inventory is stated at last-in, first-out (LIFO) cost. As a
result of a regulatory accounting procedure, the pricing of gas in storage does
not have any effect on net income. If the first-in, first-out (FIFO) method of
accounting for gas in storage inventory had been used by SoCalGas, inventory
would have been higher than reported at December 31, 1995 and 1994 by $21
million and $34 million, respectively. Other inventories are generally stated at
the lower of cost, determined on an average cost basis, or market.
PROPERTY, PLANT AND EQUIPMENT
The costs of additions, renewals and improvements to utility plant are charged
to the appropriate plant accounts. These costs include labor, material, other
direct costs, indirect charges, and an allowance for funds used during
construction. The cost of utility plant retired or otherwise disposed of, plus
removal costs and less salvage, is charged to accumulated depreciation.
Depreciation is recorded on the
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
PAGE 38 PACIFIC ENTERPRISES
straight-line remaining-life basis. The depreciation methods are consistent with
those used by non-regulated entities.
ALLOWANCE FOR FUNDS USED DURING CONSTRUCTION (AFUDC)
AFUDC represents the cost of funds used to finance the construction of utility
plant and is added to the cost of utility plant. Interest expense of $9 million
in 1995, $4 million in 1994 and $7 million in 1993 was capitalized.
OTHER
Cash equivalents include short-term investments purchased with maturities of
less than 90 days.
The preparation of financial statements in conformity with GAAP requires
management to make estimates and assumptions that affect the reported amounts of
assets and liabilities and disclosure of contingent assets and liabilities at
the date of the financial statements and the reported amounts of revenues and
expenses during the reporting period. Actual results could differ from those
estimates.
2. DISCONTINUED OPERATIONS AND QUASI-REORGANIZATION
During 1993, the Company completed a strategic plan to refocus on its natural
gas utility and related businesses. The strategy included the divestiture of its
retailing operations and substantially all of its oil and gas exploration and
production business. In connection with the divestitures, the Company effected a
quasi-reorganization for financial reporting purposes, effective December 31,
1992. Fair value adjustments charged to common stock totaled $190 million.
Additionally, the accumulated deficit in retained earnings of $452 million at
December 31, 1992 was eliminated by a reduction in the common stock account.
In connection with the sale of its retailing operations, the Company
assumed the retailing group's Employee Stock Ownership Plan (ESOP) and related
indebtedness (see Notes 8 and 12). In addition, the retailing group's buyer
agreed to reimburse the Company for a portion of the ESOP quarterly debt
service. In April 1994, the Company received a $65 million payment from the
buyer. This payment primarily reflected the settlement of the buyer's remaining
debt service obligation. It also canceled a warrant granted to the Company in
connection with the sale of retailing operations to purchase approximately 10%
of the buyer's common stock. Since the sale of the retailing operations was
recorded prior to the quasi-reorganization, the settlement and resolution of
other contingencies related to the ESOP resulted in a $114 million increase to
shareholders' equity, of which $37 million was to common stock.
The receipt of $65 million is reflected in cash from discontinued
operations in the consolidated statement of cash flows.
Certain of the liabilities established in connection with discontinued
operations and the quasi-reorganization were favorably resolved in 1995,
including the sale of ownership in the Company's headquarters building and
settlement of certain lawsuits remaining from the oil and gas operations. Excess
reserves of $13 million resulting from the favorable resolution of these issues
have been added to shareholders' equity. Other liabilities will be resolved in
future years. As of December 31, 1995, the provisions for these matters are
adequate.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
PAGE 39 PACIFIC ENTERPRISES
3. REGULATORY MATTERS
RESTRUCTURING OF GAS SUPPLY CONTRACTS
In 1993, SoCalGas and the Company's gas supply subsidiaries restructured long-
term gas supply contracts with suppliers of California offshore and Canadian
gas. In the past, SoCalGas' cost of these supplies had been substantially in
excess of its average delivered cost of gas for all gas supplies.
The restructured contracts substantially reduced the ongoing delivered
costs of these gas supplies and provided lump sum payments totaling $391 million
to the suppliers. The expiration date for the Canadian gas supply contract was
shortened from 2012 to 2003.
COMPREHENSIVE SETTLEMENT OF REGULATORY ISSUES
On July 20, 1994, the CPUC approved a comprehensive settlement (Comprehensive
Settlement) of a number of pending regulatory issues including rate recovery of
a significant portion of the restructuring costs associated with long-term gas
supply contracts discussed above. The Comprehensive Settlement permits SoCalGas
to recover in utility rates approximately 80% of the contract restructuring
costs of $391 million and accelerated amortization of related pipeline assets of
approximately $140 million, together with interest, over a period of
approximately five years. In addition to the gas supply issues, the
Comprehensive Settlement addresses the following other regulatory issues:
- - NONCORE CUSTOMER RATES The Comprehensive Settlement changed the procedures
for determining noncore rates to be charged by SoCalGas to its customers
for the five-year period commencing August 1, 1994. Rates charged to the
customers are established based upon SoCalGas' recorded throughput to these
customers for 1991. SoCalGas will bear the full risk of any declines in
noncore deliveries from 1991 levels. Any revenue enhancement from
deliveries in excess of 1991 levels will be limited by a crediting account
mechanism that will require a credit to customers of 87.5% of revenues in
excess of certain limits. These annual limits above which the credit is
applicable increase from $11 million to $19 million over the five-year
period from August 1, 1994 through July 31, 1999. The Company's ability to
report as earnings the results from revenues in excess of SoCalGas'
authorized return from noncore customers due to volume increases has been
eliminated for the five years beginning August 1, 1994 as a consequence of
the Comprehensive Settlement described above. This is because forecasted
deliveries in excess of the 1991 throughput levels used to establish
noncore rates were contemplated in estimating the costs of the
Comprehensive Settlement at December 31, 1993.
- - REASONABLENESS REVIEWS The Comprehensive Settlement includes settlement of
all pending reasonableness reviews with respect to SoCalGas' gas purchases
from April 1989 through March 1992, as well as certain other future
reasonableness review issues.
- - GAS COST INCENTIVE MECHANISM On March 16, 1994, the CPUC approved a new
process for evaluating SoCalGas' gas purchases, substantially replacing the
previous process of reasonableness reviews. The Gas Cost Incentive
Mechanism (GCIM) is a three-year pilot program which began April 1, 1994.
The gcim essentially compares SoCalGas' cost of gas with a
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
PAGE 40 PACIFIC ENTERPRISES
benchmark level, which is the average price of 30-day firm spot supplies
delivered to the SoCalGas market area.
SoCalGas can recover costs in excess of the benchmark to the extent
they fall within a tolerance band, which extends to 4% above the benchmark.
If SoCalGas' cost of gas exceeds the tolerance level, then the excess cost
will be shared equally between ratepayers and shareholders. All savings
from gas purchased below the benchmark are shared equally between
ratepayers and shareholders. For the first year of the program, ended March
31, 1995, gas purchases were within the established 4.5% tolerance band.
- - ATTRITION ALLOWANCES The Comprehensive Settlement authorizes SoCalGas an
annual allowance for increases in operating and maintenance expenses for
1996 to the extent that the projected annual inflation rate exceeds 3%. In
1995 attrition was calculated on the inflation rate in excess of 2%. The
rate base attrition will continue to be based upon a three year rolling
average of recorded net utility plant additions. This is a departure from
past regulatory practice of allowing recovery in rates of the full effect
of inflation on operating and maintenance expenses. SoCalGas intends to
continue to attempt to control operating expenses and investment to amounts
authorized in rates to offset the effect of this regulatory change. The
most recent decision issued by the CPUC in December 1995 authorized
SoCalGas to collect $12 million in rates for the 1996 attrition allowance.
The Company recorded the impact of the Comprehensive Settlement in
1993 and, upon giving effect to liabilities previously recognized at the
Company and SoCalGas, the costs of the Comprehensive Settlement, including
the restructuring of gas supply contracts, did not result in any additional
charge to the Company's consolidated earnings.
In the most recent decision issued by the CPUC in December 1995,
SoCalGas has been authorized to reduce rates by $50 million effective
January 1, 1996. The reduction is comprised of the following:
Increase
(Dollars in millions) (Decrease)
- -------------------------------------------------------
1996 Cost of Capital $ (12)
BCAP: Core (94)
Noncore 20
1996 Attrition Allowances 12
1994 Earthquake Costs 22
Other 2
-----
$ (50)
- -------------------------------------------------------
- -------------------------------------------------------
Regulatory Accounts Receivable and Regulatory Assets include a total of
approximately $259 million and $327 million in 1995 and 1994, respectively, for
the recovery of costs as provided in the Comprehensive Settlement. The CPUC
authorized the borrowing of $425 million primarily to provide for funds needed
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
PAGE 41 PACIFIC ENTERPRISES
under the Comprehensive Settlement. As of December 31, 1995, SoCalGas has $265
million in commercial paper remaining outstanding related to the Comprehensive
Settlement (See Note 7).
4. INCOME TAXES
A reconciliation of the difference between computed statutory federal income tax
expense and actual income tax expense for operations is as follows:
Year Ended December 31
-------------------------------------
(Dollars in Millions) 1995 1994 1993
- -------------------------------------------------------------------------------------
Computed statutory
federal income tax
expense $ 110 $ 109 $ 108
Increases (reductions)
resulting from:
Depreciation and
other items not
deferred-SoCalGas 20 17 18
Capitalized expenses
not deferred
- SoCalGas (10) (6)
Federal income tax
rate change (8)
State income taxes-net
of federal income
tax benefit 20 17 16
Research and
development credit (6)
Investment tax credits (3) (3) (4)
Other, net (8) 5 2
------------------------------------
Income tax expense
from operations $ 129 $ 139 $ 126
- -------------------------------------------------------------------------------------
- -------------------------------------------------------------------------------------
The components of income tax expense for operations are as follows:
Year Ended December 31
------------------------------------
(Dollars in Millions) 1995 1994 1993
- -------------------------------------------------------------------------------------
Federal
Current $ 70 $ 79 $ 59
Deferred 28 34 38
-----------------------------------
98 113 97
-----------------------------------
State
Current 32 26 17
Deferred (1) 12
-----------------------------------
31 26 29
-----------------------------------
Total
Current 102 105 76
Deferred 27 34 50
-----------------------------------
$ 129 $ 139 $ 126
- -------------------------------------------------------------------------------------
- -------------------------------------------------------------------------------------
The principal components of net deferred tax liabilities are as follows:
December 31, 1995
---------------------------------------
(Dollars in Millions) Assets Liabilities Total
- -------------------------------------------------------------------------------------
Accelerated depreciation
for tax purposes $ (489) $ (489)
Comprehensive
Settlement $ 159 (77) 82
Regulatory accounts
receivable (104) (104)
Postretirement benefits 90 90
Restructuring costs
deferred for
tax purposes 58 58
Deferred investment
tax credits 30 30
Partnership income (45) (45)
Customer advances for
construction 21 21
Regulatory asset (120) (120)
Other regulatory 119 (46) 73
AMT carryforward 74 74
Other 134 (33) 101
------------------------------------
Total deferred
income tax
assets (liabilities) $ 685 $ (914) $ (229)
- -------------------------------------------------------------------------------------
- -------------------------------------------------------------------------------------
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
PAGE 42 PACIFIC ENTERPRISES
December 31, 1994
---------------------------------------
(Dollars in Millions) Assets Liabilities Total
- -------------------------------------------------------------------------------------
Accelerated depreciation
for tax purposes $ (417) $ (417)
Comprehensive
Settlement $ 212 (108) 104
Regulatory accounts
receivable (151) (151)
Postretirement benefits 95 95
Restructuring costs
deferred for
tax purposes 78 78
Deferred investment
tax credits 31 31
Partnership income (45) (45)
Customer advances for
construction 26 26
Regulatory asset (135) (135)
Other regulatory 109 (62) 47
amt carryforward 93 93
Other 100 (17) 83
------------------------------------
Total deferred
income tax
assets (liabilities) $ 744 $ (935) $ (191)
- -------------------------------------------------------------------------------------
- -------------------------------------------------------------------------------------
In 1994, the Company utilized all of its remaining net operating loss
carryforward for federal income tax purposes. No valuation allowance has been
provided for deferred tax assets since they are expected to be realized through
either reversal of existing temporary differences or future taxable income.
SoCalGas generally provides for income taxes on the basis of amounts
expected to be paid currently, except for the provision for deferred taxes on
regulatory accounts, customer advances for construction and accelerated
depreciation of property placed in service after 1980. In addition, SoCalGas
recognizes certain other deferred tax liabilities (primarily accelerated
depreciation of property placed in service prior to 1981 and deferred investment
tax credits) which are expected to be recovered through future rates. At
December 31, 1995 and 1994, $109 million and $97 million, respectively, of
deferred income taxes have been offset by an equivalent amount in regulatory
assets.
5. COMMITMENTS AND CONTINGENT LIABILITIES
ENVIRONMENTAL OBLIGATIONS
SoCalGas has identified and reported to California environmental authorities 42
former manufactured gas plant sites for which it (together with other
utilities as to 21 of these sites) may have remedial obligations under
environmental laws. As of December 31, 1995, nine of these sites have been
remediated, of which five have received certification from the California
Environmental Protection Agency. Preliminary investigations, at a minimum, have
been completed on 39 of the gas plant sites, including those sites at which the
remediations described above have been completed. In addition, the Company and
its subsidiaries have been named as potentially responsible parties for two
landfill sites and four industrial waste disposal sites.
On May 4, 1994, the CPUC approved a collaborative settlement between
SoCalGas and other California energy utilities and the Division of Ratepayer
Advocates which provides for rate recovery of 90% of environmental investigation
and remediation costs without reasonableness review. In addition, the utilities
have the opportunity to retain a percentage of any insurance recoveries to
offset the 10% of costs not recovered in rates.
At December 31, 1995, SoCalGas' estimated remaining investigation and
remediation liability was
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
PAGE 43 PACIFIC ENTERPRISES
$76 million, of which 90% is authorized to be recovered through the mechanism
discussed above. The estimated liability is subject to future adjustment pending
further investigation. The Company believes that any costs not ultimately
recovered through rates, insurance or other means, upon giving effect to
previously established liabilities, will not have a material adverse effect on
the Company's financial statements.
LITIGATION
The Company is a defendant in various lawsuits arising in the normal course of
business. Management believes that the resolution of these pending claims and
legal proceedings will not have a material adverse effect on the Company's
financial statements.
OBLIGATIONS UNDER FIRM COMMITMENTS
The Company has commitments for firm pipeline capacity under contracts with
pipeline companies that expire at various dates through the year 2006. These
agreements provide for payments of an annual demand or reservation charge. The
Company recovers such fixed charges in rates. Estimated minimum commitments as
of December 31, 1995 are as follows: 1996 - $258 million, 1997 - $222 million,
1998 - $244 million, 1999 - $244 million, 2000 - $244 million, after 2000 -
$1,327 million.
OTHER COMMITMENTS AND CONTINGENCIES
At December 31, 1995, commitments for capital expenditures were approximately
$27 million.
6. LEASES
The Company and its subsidiaries have leases on real and personal property
expiring at various dates from 1996 to 2011. The rentals payable under these
leases are determined on both fixed and percentage bases and most leases contain
options to extend which are exercisable by the Company or the subsidiaries.
Rental expense under space operating leases was $66 million, $63 million
and $63 million in 1995, 1994 and 1993, respectively.
The following is a schedule of future minimum operating lease commitments
as of December 31, 1995:
Future Minimum
(Dollars in Millions) Lease Payments
- -------------------------------------------
Year Ended December 31:
1996 $ 51
1997 51
1998 48
1999 48
2000 49
Later years 413
-------
Total $ 660
- -------------------------------------
- -------------------------------------
In connection with the quasi-reorganization and loss on disposal of
discontinued operations (see Note 2), the Company established reserves of
$102 million to fair value operating leases related to its headquarters and
other leases at December 31, 1992. The remaining amount of these reserves
was $85 million at December 31, 1995.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
PAGE 44 PACIFIC ENTERPRISES
7. COMPENSATING BALANCES AND SHORT-TERM BORROWING ARRANGEMENTS
The Parent has a $300 million multi-year credit agreement requiring annual fees
of .09%. SoCalGas has an additional $650 million multi-year credit agreement
requiring annual fees of .075%. The interest rates on these lines vary and are
derived from formulas based on market rates and the Companies' credit ratings.
The multi-year credit agreements expire in February 2001. At December 31, 1995,
all bank lines of credit were unused. The unused bank lines of credit provide
backing for SoCalGas' commercial paper program.
At December 31, 1995 and 1994, SoCalGas had $415 million and $524 million,
respectively, of commercial paper obligations outstanding. The weighted average
annual interest rate of commercial paper obligations outstanding was 5.66% and
5.96% at December 31, 1995 and 1994, respectively. At December 31, 1995, the
Company has classified $181 million of the commercial paper as long-term debt
since it is the Company's intent (supported by the $650 million multi-year
credit agreement above) to continue to refinance that portion of the debt on
a long-term basis.
8. LONG-TERM DEBT
December 31
----------------------
(Dollars in Millions) 1995 1994
- ----------------------------------------------------------------------
SOUTHERN CALIFORNIA GAS COMPANY
First Mortgage Bonds:
6 1/2% December 15, 1997 $ 125 $ 125
5 1/4% March 1, 1998 100 100
6 7/8% August 15, 2002 100 100
5 3/4% November 15, 2003 100 100
9 3/4% December 1, 2020 18
8 3/4% October 1, 2021 150 150
7 3/8% March 1, 2023 100 100
7 1/2% June 15, 2023 125 125
6 7/8% November 1, 2025 175 175
Other Long-Term Debt:
4.69% Notes, June 16, 1995 31
8 3/4% Notes, August 4, 1995 20
5.03% - 5.05% Notes,
August 28 - September 1, 1995 28
5.81% - 5.85% Notes, December 1, 1995 7
8 3/4% Notes, July 8, 1996 20 20
5.98% Notes, August 28, 1997 22 22
8 3/4% Notes, July 6, 2000 10 10
SFr. 150,000,000 7 1/2%
Foreign Interest Payment
Securities, May 14, 1996 75 75
SFr. 100,000,000 5 1/8% Bonds,
February 6, 1998 (Foreign currency
exposure hedged through currency
swap at an interest rate of 9.725%) 47 47
5.66% Commercial Paper,
February 8, 2001 181 246
----------------------
1,330 1,499
PACIFIC INTERSTATE COMPANIES
7.65%-1995 39
OTHER
8.0%-10.0% 1999-2003 26 26
----------------------
Total 1,356 1,564
----------------------
Less:
Long-term debt due within one year 100 128
Unamortized debt discount
less premium 15 16
----------------------
115 144
----------------------
Long-Term Debt $ 1,241 $ 1,420
- ----------------------------------------------------------------------
- ----------------------------------------------------------------------
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
PAGE 45 PACIFIC ENTERPRISES
The annual principal payment requirements of long-term debt, including debt
of the Employee Stock Ownership Plan, for the years 1996 through 2000 are $100
million, $150 million, $150 million, $133 million, and $13 million,
respectively. Substantially all of utility plant serves as collateral for the
First Mortgage Bonds, and certain assets of the nonutility subsidiaries are
pledged as collateral for their obligations.
DEBT OF EMPLOYEE STOCK OWNERSHIP PLAN AND
TRUST (TRUST) (SEE NOTE 12).
The TRUST covers substantially all employees and is used to fund the Company's
retirement savings program. It has an ESOP feature and holds approximately 2.3
million shares of common stock of the Company. The variable rate ESOP debt held
by the TRUST bears interest at a rate necessary to place or remarket the notes
at par. Principal is due on November 30, 1999 and interest is payable monthly
through 1999. The Company is obligated to make contributions to the TRUST
sufficient to satisfy debt service requirements. The debt is scheduled to mature
in 1999. As the Company makes contributions to the TRUST, these contributions,
plus any dividends paid on the unallocated shares of the Company's common stock
held by the TRUST, will be used to repay the debt. As dividends are increased or
decreased, required contributions are reduced or increased, respectively.
Interest on ESOP debt amounted to $7 million in 1995, $5 million in 1994 and $6
million in 1993. Dividends used for debt service amounted to $3 million, $3
million and $2 million in 1995, 1994 and 1993, respectively, and are deductible
for federal income tax purposes.
CURRENCY RATE SWAPS
In February 1986, SoCalGas issued SFr. 100 million of 5 1/8% bonds which will
mature on February 6, 1998. SoCalGas has entered into a swap transaction with a
major international bank to hedge the currency exposure. The terms of the swap
result in a U.S. dollar liability of $47 million at an interest
rate of 9.725% with the principal payable on February 6, 1998.
In May 1986, SoCalGas issued SFr. 150 million of 7 1/2% Foreign Interest
Payment Securities which are renewable at 10-year intervals at reset interest
rates. Interest is payable in U.S. dollars. The principal was exchanged into $75
million at an exchange rate of 1.9925, which is also the minimum rate of
exchange for determining the amount of principal repayable in Swiss francs.
INTEREST RATE SWAPS
At December 31, 1994, the Company had outstanding interest rate swaps related to
continuing operations which effectively set $100 million of ESOP debt to a fixed
7.3% until September 15, 1995 and an interest rate swap related to discontinued
operations which set the interest rate on $100 million of long-term debt to a
fixed 9.12% until September 5, 1995. These swaps were not renewed.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
PAGE 46 PACIFIC ENTERPRISES
9. FINANCIAL INSTRUMENTS
The carrying amount of cash and cash equivalents approximates fair value because
of the short maturity of those instruments. The Flexible Auction Preferred
Stocks of SoCalGas approximate fair value since they are remarketed
periodically. The debt of the ESOP approximates fair market value based on rates
currently available to the Company for debt with similar terms and maturity.
The fair value of interest rate swaps is the estimated amount that the bank
would receive or pay to terminate the swap agreements at the reporting date,
taking into account current interest rates and the current credit worthiness of
the swap counterparties. The carrying amount of interest rate and currency rate
swaps approximates fair value.
The fair value of SoCalGas' long-term debt, 6% preferred, 6% Series A
preferred and 7 1/4% preferred stock is estimated based on the quoted market
prices for the same or similar issues or on the current rates offered to
SoCalGas for debt of similar remaining maturities. The fair value of these
financial instruments is different from the carrying amount. These instruments
were not adjusted to fair value in the quasi-reorganization because they
represent obligations of the rate regulated subsidiaries which are recoverable
in future rates.
The following financial instruments have a fair value which is different
from the carrying amount as of December 31.
Carrying Fair
(Dollars in Millions) Amount Value
- ----------------------------------------------------------------------
1995:
Long-Term Debt of SoCalGas $ 1,315 $ 1,278
Preferred Stocks of SoCalGas $ 95 $ 92
1994:
Long-Term Debt of SoCalGas $ 1,483 $ 1,377
Preferred Stocks of SoCalGas $ 95 $ 77
- ----------------------------------------------------------------------
- ----------------------------------------------------------------------
As a result of the GCIM (See Note 3), SoCalGas enters into a certain amount
of gas futures contracts in the open market with the intent of reducing gas
costs within the GCIM tolerance band. SoCalGas' policy is to use gas futures
contracts to mitigate risk and better manage gas costs. The CPUC has approved
the use of gas futures for managing risk associated with the GCIM. For the year
ended December 31, 1995, gains or losses from gas futures contracts are not
material to the Company's financial statements.
10. PREFERRED STOCKS OF A SUBSIDIARY
The amount of preferred stocks of SoCalGas outstanding at December 31 is as
follows:
Number Millions
of Shares of Dollars
- ----------------------------------------------------------------------
1995:
6%, $25 par value 29,507 $ 1
6% Series A, $25 par value 783,032 19
Series Preferred, no par value
Flexible Auction, Series A 500 50
Flexible Auction, Series C 500 50
7 3/4%, $25 Stated Value 3,000,000 75
-------
$ 195
-------
1994:
6%, $25 par value 29,642 $ 1
6% Series A, $25 par value 783,032 19
Series Preferred, no par value
Flexible Auction, Series A 500 50
Flexible Auction, Series C 500 50
7 3/4%, $25 Stated Value 3,000,000 75
-------
$ 195
- ----------------------------------------------------------------------
- ----------------------------------------------------------------------
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
PAGE 47 PACIFIC ENTERPRISES
Each issue of the Flexible Auction Series Preferred Stock is auctioned on
specified dividend dates. The term of each subsequent dividend period is, at
SoCalGas' option, 49 days or longer, not to exceed ten years. The weighted
average dividend rates for the Flexible Auction Preferred Stock for 1995, 1994
and 1993 were: Series A, 4.80%, 3.40% and 2.67%, respectively; and, Series C,
4.18%, 3.33% and 2.75%, respectively. Subsequent dividend rates may be affected
by general market conditions and the credit rating assigned to the Flexible
Auction Series Preferred Stock. SoCalGas has the option of redeeming the shares,
in whole or in part, at $100,000 per share plus accumulated dividends on any
scheduled dividend payment date.
11. PREFERRED STOCK
The Company has 1,100 shares of Remarketed Preferred (RP) Stock outstanding with
a liquidation preference of $100,000 per share. The RP shares are remarketed by
designated agents at specified dividend dates. In connection with the
remarketing process, the holders of the shares may elect dividend periods of
seven or 49 days. The dividend rate may be affected by general market conditions
and the credit rating assigned to the RP shares.
The weighted average dividend rates for 1995 and 1994 were 4.9%. The
Company has the option of redeeming the RP shares, in whole or in part, at
$100,000 per share plus accumulated dividends on any scheduled dividend payment
date.
All or any part of every series of presently outstanding preferred stock is
subject to redemption at the Company's option at any time upon not less than 30
days notice, at the applicable redemption prices for each series, together with
the accrued and accumulated dividends to the date of redemption. None of the
outstanding issues of preferred stock has any conversion rights. During 1995,
the Company redeemed 300,000 shares of the $7.64
dividend preferred stock and 100 shares of $4.75 dividend preferred stock. In
1994, the Company repurchased 400 shares of Remarketed, Series A preferred
stock.
The number of shares of preferred stock and class A preferred stock authorized
and outstanding is as follows:
December 31, 1995 December 31, 1994
Redemption ------------------------- -------------------------
Price Shares Shares Shares Shares
Per Share Authorized Outstanding Authorized Outstanding
- -------------------------------------------------------------------------------------------------------------------
Preferred stock -
cumulative, no par value:
Remarketed, Series A $ 100,000.00 1,500 1,100 1,500 1,100
$7.64 Dividend 101.00 300,000 0 300,000 300,000
$4.75 Dividend 100.00 200,000 200,000 200,000 200,000
$4.50 Dividend 100.00 300,000 300,000 300,000 300,000
$4.40 Dividend 101.50 100,000 100,000 100,000 100,000
$4.36 Dividend 101.00 200,000 200,000 200,000 200,000
$4.75 Dividend 101.00 353 253 353 353
Unclassified 8,898,147 8,898,147
--------------------------------------------------------
Total preferred 10,000,000 801,353 10,000,000 1,101,453
--------------------------------------------------------
Class A preferred stock -
cumulative, no par value 5,000,000 5,000,000
- -------------------------------------------------------------------------------------------------------------------
- -------------------------------------------------------------------------------------------------------------------
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
PAGE 48 PACIFIC ENTERPRISES
12. PENSION, POSTRETIREMENT AND OTHER EMPLOYEE BENEFIT PLANS
PENSION PLANS
The Company and certain subsidiaries have noncontributory defined benefit
pension plans covering substantially all of their employees. Over 90% of the
employees covered by the plans are employed by SoCalGas. Benefits are based on
an employee's years of service and compensation during his or her last years of
employment. The Company's policy is to fund the plans annually at a level which
is fully deductible for federal income tax purposes and as necessary on an
actuarial basis to provide assets sufficient to meet the benefits to be paid to
plan members.
Pension expense for continuing operations was as follows:
Year Ended December 31
-------------------------
(DOLLARS IN MILLIONS) 1995 1994 1993
- ----------------------------------------------------------------------
Service cost-benefits earned
during the period $ 27 $ 36 $ 34
Interest cost on projected
benefit obligation 91 87 84
Actual return on plan assets (333) (1) (160)
Net amortization and deferral 223 (102) 57
-------------------------
Net periodic pension cost 8 20 15
Special early retirement program 18 12 18
Regulatory adjustment 2 (3) 1
-------------------------
Total pension expense $ 28 $ 29 $ 34
- ----------------------------------------------------------------------
- ----------------------------------------------------------------------
A reconciliation of the plans' funded status to the pension liability
recognized in the Consolidated Balance Sheet is as follows:
December 31
-----------------
(DOLLARS IN MILLIONS) 1995 1994
- ----------------------------------------------------------------------
Actuarial present value of pension
benefit obligations:
Accumulated benefit obligation,
including $1,060 and $824 in
vested benefits at December 31,
1995 and 1994, respectively $ 1,195 $ 920
Effect of future salary increases 298 215
-----------------
Projected benefit obligation 1,493 1,135
Less: plan assets at fair value, primarily
publicly traded common stocks
and equity pooled funds (1,603) (1,312)
Unrecognized net gain 191 254
Unrecognized prior service cost (44) (40)
Unrecognized transition obligation (5) (6)
-----------------
Accrued pension liability included in
the Consolidated Balance Sheet $ 32 $ 31
-----------------
The plans' major actuarial assumptions
include:
Weighted average discount rate 6.85 % 8.00 %
Rate of increase in future
compensation levels 5.00 % 5.00 %
Expected long-term rate of
return on plan assets 8.00 % 8.00 %
- ----------------------------------------------------------------------
- ----------------------------------------------------------------------
POSTRETIREMENT BENEFIT PLAN
In 1992, the Company adopted Statement of Financial Accounting Standards No.
106, "Employers' Accounting for Postretirement Benefits Other Than Pensions"
(SFAS 106). SFAS 106 requires the accrual of the cost of certain postretirement
PAGE 49 PACIFIC ENTERPRISES
benefits other than pensions over the active service period of the employee. The
Company previously recorded these costs when paid or funded. SFAS 106 allows
amortization of the cumulative adjustment over 20 years. However, at December
31, 1992, the Company implemented a quasi-reorganization and accrued the
postretirement liability at its entire fair value. The CPUC and the FERC in late
1992 authorized SFAS 106 amounts to be recovered in rates for the regulated
entities. Therefore, a regulatory asset has been recorded to reflect the portion
of the liability which will be recovered in future rates.
The Company's postretirement benefit plans currently provide medical and
life insurance benefits to qualified retirees. In the past, employee cost-
sharing provisions have been implemented to control the increasing costs of
these benefits. Other changes could occur in the future. The Company's policy is
to fund these benefits at a level which is fully tax deductible for federal
income tax purposes, not to exceed amounts recoverable in rates for regulated
companies, and as necessary on an actuarial basis to provide assets sufficient
to be paid to plan participants. The net periodic postretirement benefit expense
was as follows:
Year Ending December 31
(Dollars in Millions) 1995 1994 1993
- ----------------------------------------------------------------------
Service cost-benefits earned
during the period $13 $14 $12
Interest cost on projected
benefit obligation 31 28 28
Actual return on plan assets (37) (1) (10)
Net amortization and deferral 23 (10) 3
------------------------
Net periodic postretirement
benefit cost 30 31 33
Regulatory adjustment 13 13 13
------------------------
Net postretirement benefit
expense $43 $44 $46
- ----------------------------------------------------------------------
- ----------------------------------------------------------------------
A reconciliation of the plan's funded status to the postretirement
liability recognized in the Consolidated Balance Sheet is as follows:
December 31
----------------
(Dollars in Millions) 1995 1994
- ----------------------------------------------------------------------
Accumulated postretirement
benefit obligation:
Retirees $ 193 $ 168
Fully eligible active plan participants 255 189
Other active plan participants 24 19
----------------
472 376
Less: plan assets at fair value,
primarily publicly traded
common stocks and equity
pooled funds (217) (147)
Unrecognized prior service cost 15 16
Unrecognized net loss (35)
----------------
Net postretirement benefit liability
included in the Consolidated
Balance Sheet $ 235 $ 245
----------------
The plan's major actuarial
assumptions include:
Health care cost trend rate 7.50 % 8.00 %
Weighted average discount rate 6.85 % 8.00 %
Rate of increase in future
compensation levels 5.00 % 5.00 %
Expected long-term rate of
return on plan assets 8.00 % 8.00 %
- ----------------------------------------------------------------------
The assumed health care cost trend rate is 7.5% for 1996. The trend rate is
expected to decrease from
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
PAGE 50 PACIFIC ENTERPRISES
1996 to 1998 with a 6.5% ultimate trend rate thereafter. The effect of a one-
percentage-point increase in the assumed health care cost trend rate for each
future year is $8.6 million on the aggregate of the service and interest cost
components of net periodic postretirement cost for 1995 and $63.6 million on the
accumulated postretirement benefit obligation at December 31, 1995. The
estimated income tax rate used in the return on plan assets is zero since the
assets are invested in tax exempt funds.
POSTEMPLOYMENT BENEFITS
At December 31, 1992, the Company adopted Statement of Financial Accounting
Standards No. 112, "Employers' Accounting for Postemployment Benefits" (SFAS
112). SFAS 112 requires the accrual of the obligation to provide benefits to
former or inactive employees after employment but before retirement. There was
no impact on earnings since these costs are currently recovered in rates as
paid, and as such, have been reflected as a regulatory asset. At December 31,
1995 and 1994 the liability was $45 million and $50 million, respectively, and
represents primarily workers compensation and disability
benefits.
RETIREMENT SAVINGS PLAN
Upon completion of one year of service, all employees of the Company and certain
subsidiaries are eligible to participate in the Company's retirement savings
plan administered by bank trustees. Employees may contribute from 1% to 14% of
their regular earnings. The Company generally contributes an amount of cash or a
number of shares of the Company's common stock of equivalent fair market value
which, when added to prior forfeitures, will equal 50% of the first 6% of
eligible base salary contributed by employees. The employees' contributions, at
the direction of the employees, are primarily invested in the Company's common
stock, mutual funds or guaranteed investment contracts. In 1993, 1994 and 1995
the Company's contributions were partially funded by the Pacific Enterprises
Employee Stock Ownership Plan and Trust. The Company's compensation expense was
$8 million in 1995 and $9 million in both 1994 and 1993.
EMPLOYEE STOCK OWNERSHIP PLAN
The Company retained Pacific Enterprises Employee Stock Ownership Plan and Trust
(TRUST) subsequent to the sale of the retailing operations in 1992 (see Notes 2
and 8). The TRUST covers substantially all employees and is used to fund the
Company's retirement savings plan program. All contributions to the TRUST are
made by the Company and there are no contributions by the participants.
On January 1, 1994, the Company adopted the provisions of the American
Institute of Certified Public Accountants Statement of Position No. 93-6
PAGE 51 PACIFIC ENTERPRISES
(SOP 93-6), "Employers' Accounting for Employee Stock Ownership Plans." SOP 93-6
does not treat unallocated shares held by the ESOP as outstanding for accounting
purposes. As a result, the weighted average shares of common stock outstanding
in 1994 were reduced by 2.5 million shares, which favorably impacted earnings
per share by $.06 for the year ended December 31, 1994. The adoption of SOP 93-6
had no impact on earnings. Since the unallocated shares held by the ESOP are
treated as unissued, SOP 93-6 requires that when unallocated shares are released
to employees' accounts they be accounted for at market value as newly issued
shares. As the Company makes contributions to the ESOP, the ESOP debt service is
paid and shares are released proportionately to the total expected debt service.
Compensation expense is charged and equity is credited for the market value
of the shares released. However, tax deductions are allowed based on the cost of
the shares. Dividends on unallocated shares are used to pay debt service and are
charged against liabilities. The TRUST held 2.3 million and 2.4 million shares
of common stock with fair values of $65.5 million and $51.4 million at December
31, 1995 and 1994, respectively.
13. STOCK BASED COMPENSATION
In October 1995, Statement of Financial Accounting Standards No. 123,
"Accounting for Stock Based Compensation" (SFAS 123) was issued. This statement
establishes a fair-value-based method of accounting for employee stock options
or similar equity instruments and encourages all companies to adopt that method
of accounting for all of their employee stock compensation plans.
SFAS 123 allows companies to continue to measure compensation cost for
employee stock options or similar equity instruments using the method of
accounting prescribed by Accounting Principles Board Opinion No. 25, "Accounting
for Stock Issued to Employees." Companies electing to remain with this method
are required to make pro forma disclosures of net income and earnings per share
as if SFAS 123 accounting had been applied.
The Company is required to adopt the disclosure requirements of SFAS 123
for its year ending December 31, 1996. Measurement of compensation cost under
SFAS 123, if adopted, is effective for all awards granted after the beginning of
the year in which that method is first applied. Management is currently
reviewing the provisions of SFAS 123. If the fair value based measurement
provisions are adopted, they are not expected to have a material impact on the
results of operations or financial condition of the Company.
STATEMENT OF MANAGEMENT RESPONSIBILITY FOR CONSOLIDATED FINANCIAL STATEMENTS
PAGE 52 PACIFIC ENTERPRISES
The consolidated financial statements have been prepared by management. The
integrity and objectivity of these financial statements and the other financial
information in the Annual Report, including the estimates and judgments on which
they are based, are the responsibility of management. The financial statements
have been audited by Deloitte & Touche LLP, independent certified public
accountants, appointed by the Board of Directors. Their report is shown on page
53. Management has made available to Deloitte & Touche LLP all of the Company's
financial records and related data, as well as the minutes of shareholders' and
directors' meetings.
Management maintains a system of internal accounting control which it
believes is adequate to provide reasonable, but not absolute, assurance that
assets are properly safeguarded and accounted for, that transactions are
executed in accordance with management's authorization and are properly recorded
and reported, and for the prevention and detection of fraudulent financial
reporting. Management monitors the system of internal control for compliance
through its own review and a strong internal auditing program which also
independently assesses the effectiveness of the internal controls. In
establishing and maintaining internal controls, the Company must exercise
judgment in determining whether the benefits to be derived justify the costs of
such controls.
Management acknowledges its responsibility to provide financial information
(both audited and unaudited) that is representative of the Company's operations,
reliable on a consistent basis, and relevant for a meaningful financial
assessment of the Company. Management believes that the control process enables
them to meet this responsibility.
Management also recognizes its responsibility for fostering a strong
ethical climate so that the Company's affairs are conducted according to the
highest standards of personal and corporate conduct. This responsibility is
characterized and reflected in the Company's code of corporate conduct, which is
publicized throughout the Company. The Company maintains a systematic program to
assess compliance with this policy.
The Board of Directors has an Audit Committee composed solely of directors
who are not officers or employees. The Committee recommends for approval by the
full Board the appointment of the independent auditors. The Committee meets
regularly with management, with the Company's internal auditors, and with the
independent auditors. The independent auditors and the internal auditors
periodically meet alone with the Audit Committee and have free access to the
Audit Committee at any time.
/S/Willis B. Wood, Jr.
Willis B. Wood, Jr.
CHAIRMAN AND CHIEF EXECUTIVE OFFICER
/S/Larry J. Dagley
Larry J. Dagley
SENIOR VICE PRESIDENT AND CHIEF FINANCIAL OFFICER
January 31, 1996
INDEPENDENT AUDITORS' REPORT
PAGE 53 PACIFIC ENTERPRISES:
PACIFIC ENTERPRISES:
We have audited the consolidated financial statements of Pacific Enterprises and
subsidiaries (pages 31 to 51) as of December 31, 1995 and 1994, and for each of
the three years in the period ended December 31, 1995. These financial
statements are the responsibility of the Company's management. Our
responsibility is to express an opinion on these financial statements based on
our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of material
misstatement. An audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An audit also includes
assessing the accounting principles used and significant estimates made by
management, as well as evaluating the overall financial statement presentation.
We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above
present fairly, in all material respects, the financial position of Pacific
Enterprises and subsidiaries as of December 31, 1995 and 1994, and the results
of their operations and their cash flows for each of the three years in the
period ended December 31, 1995 in conformity with generally accepted accounting
principles.
/S/Deloitte & Touche LLP
Los Angeles, California
January 31, 1996
SELECTED FINANCIAL DATA & COMPARATIVE STATISTICS 1985-1995
PAGE 54
(Dollars in millions, except per-share amounts) 1995 1994 1993 1992
- -----------------------------------------------------------------------------------------------------------------------------
CONSOLIDATED:
Operating revenues from continuing operations $ 2,343 $ 2,664 $ 2,899 $ 2,900
-------------------------------------------------------------
Income from continuing operations $ 185 $ 172 $ 181 $ 136
Income (loss) from discontinued operations (686)
-------------------------------------------------------------
Net income (loss) 185 172 181 (550)
Dividends on preferred stock 10 12 15 16
-------------------------------------------------------------
Net income (loss) applicable to common stock $ 175 $ 160 $ 166 $ (566)
-------------------------------------------------------------
Net income (loss) per share of common stock:
Continuing operations $ 2.12 $ 1.95 $ 2.06 $ 1.60
Discontinued operations (9.17)
-------------------------------------------------------------
$ 2.12 $ 1.95 $ 2.06 $ (7.57)
-------------------------------------------------------------
Cash dividends per share of common stock $ 1.34 $ 1.26 $ .60 $ .44
Book value per share $ 15.71 $ 14.74 $ 12.19 $ 9.44
Capital expenditures of continuing operations $ 240 $ 249 $ 331 $ 329
Total assets $ 5,259 $ 5,445 $ 5,596 $ 5,414
Capitalization:
Short-term debt $ 234 $ 278 $ 267 $ 215
Long-term debt due within one year 100 128 58 217
Long-term debt 1,241 1,420 1,262 1,774
Long-term debt of ESOP 130 130 132 141
Obligations under capital leases
Preferred stocks of a subsidiary:
Redeemable
Nonredeemable 195 195 195 195
Preferred stock 188 218 258 258
Common stock 1,111 1,092 1,048 859
Retained earnings 236 172 116
Less deferred compensation relating to ESOP (52) (54) (138) (148)
-------------------------------------------------------------
Total capitalization $ 3,383 $ 3,579 $ 3,198 $ 3,511
-------------------------------------------------------------
Number of employees 7,860 8,484 9,200 9,884
SoCalGas:
Gas revenues:
Residential $ 1,554 $ 1,713 $ 1,653 $ 1,484
Commercial/industrial 751 798 853 836
Utility electric generation 104 118 147 195
Wholesale 62 98 117 129
Exchange 1 1 4 6
-------------------------------------------------------------
Gas revenues in rates 2,472 2,728 2,774 2,650
Regulatory balancing accounts and other (193) (141) 37 190
-------------------------------------------------------------
Total operating revenue $ 2,279 $ 2,587 $ 2,811 $ 2,840
-------------------------------------------------------------
Gas volumes delivered (billion cubic feet):
Residential 239 256 248 244
Commercial/industrial 351 348 339 363
Utility electric generation 205 260 213 221
Wholesale 129 146 148 149
Exchange 13 10 17 24
-------------------------------------------------------------
Total 937 1,020 965 1,001
-------------------------------------------------------------
Core 325 341 339 335
Noncore 612 679 626 666
-------------------------------------------------------------
Total 937 1,020 965 1,001
-------------------------------------------------------------
Gas volumes sold 338 362 352 355
Gas volumes transported or exchanged 599 658 613 646
-------------------------------------------------------------
Total 937 1,020 965 1,001
-------------------------------------------------------------
Number of customers:
Residential 4,526,150 4,483,324 4,459,250 4,445,500
Commercial 184,470 187,518 187,602 189,364
Industrial 22,976 23,505 23,924 24,419
Utility electric generation/wholesale 11 11 11 10
-------------------------------------------------------------
Total number of customers 4,733,607 4,694,358 4,670,787 4,659,293
-------------------------------------------------------------
Gas purchased (billion cubic feet):
Market gas:
30-day 133 98 85 21
Other 73 149 159 198
-------------------------------------------------------------
Total market gas purchased 206 247 244 219
Affiliates 99 101 97 99
Other long-term supplies 29 36 28 42
-------------------------------------------------------------
Total gas purchased 334 384 369 360
-------------------------------------------------------------
Average cost of gas purchased excluding fixed costs
(per thousand cubic feet) $ 1.42 $ 1.68 $ 2.21 $ 2.24
Weighted average rate base $ 2,766 $ 2,862 $ 2,769 $ 2,720
Authorized rate of return on:
Rate base 9.67% 9.22% 9.99% 10.49%
Common equity 12.00% 11.00% 11.90% 12.65%
Degree days 1,215 1,459 1,203 1,258
PAGE 55 PACIFIC ENTERPRISES
1991 1990 1989 1988
--------------------------------------------------------------
CONSOLIDATED:
Operating revenues from continuing operations $ 3,007 $ 3,376 $ 3,344 $ 3,301
--------------------------------------------------------------
Income from continuing operations $ 167 $ 142 $ 142 $ 142
Income (loss) from discontinued operations (255) (201) 64 75
--------------------------------------------------------------
Net income (loss) (88) (59) 206 217
Dividends on preferred stock 16 17 13 6
--------------------------------------------------------------
Net income (loss) applicable to common stock $ (104) $ (76) $ 193 $ 211
--------------------------------------------------------------
Net income (loss) per share of common stock:
Continuing operations $ 2.09 $ 1.78 $ 1.98 $ 2.20
Discontinued operations (3.54) (2.87) .99 1.23
--------------------------------------------------------------
$ (1.45) $ (1.09) $ 2.97 $ 3.43
--------------------------------------------------------------
Cash dividends per share of common stock $ 2.62 $ 3.48 $ 3.48 $ 3.48
Book value per share $ 19.74 $ 23.07 $ 27.10 $ 28.26
Capital expenditures of continuing operations $ 335 $ 386 $ 340 $ 351
Total assets $ 5,462 $ 5,702 $ 5,874 $ 5,496
Capitalization:
Short-term debt $ 123 $ 491 $ 637 $ 572
Long-term debt due within one year 25 30 30 65
Long-term debt 1,776 1,161 1,045 1,220
Long-term debt of ESOP 149 163 173 31
Obligations under capital leases 25
Preferred stocks of a subsidiary:
Redeemable 60 60
Nonredeemable 195 145 70 20
Preferred stock 258 258 258 110
Common stock 1,458 1,385 1,331 1,066
Retained earnings 146 419 738 770
Less deferred compensation relating to ESOP (163) (173) (189) (31)
--------------------------------------------------------------
Total capitalization $ 3,967 $ 3,879 $ 4,153 $ 3,908
--------------------------------------------------------------
Number of employees 40,953 42,370 43,891 40,538
SoCalGas:
Gas revenues:
Residential $ 1,674 $ 1,548 $ 1,484 $ 1,482
Commercial/industrial 977 1,057 1,016 1,008
Utility electric generation 149 235 483 554
Wholesale 145 165 192 252
Exchange 7 8 8 12
--------------------------------------------------------------
Gas revenues in rates 2,952 3,013 3,183 3,308
Regulatory balancing accounts and other (22) 200 92 (86)
--------------------------------------------------------------
Total operating revenue $ 2,930 $ 3,213 $ 3,275 $ 3,222
--------------------------------------------------------------
Gas volumes delivered (billion cubic feet):
Residential 249 262 255 253
Commercial/industrial 460 436 400 344
Utility electric generation 170 159 202 199
Wholesale 142 139 146 144
Exchange 26 30 30 39
--------------------------------------------------------------
Total 1,047 1,026 1,033 979
--------------------------------------------------------------
Core 351 372 364 n/a
Noncore 696 654 669 n/a
--------------------------------------------------------------
Total 1,047 1,026 1,033 979
--------------------------------------------------------------
Gas volumes sold 411 515 594 654
Gas volumes transported or exchanged 636 511 439 325
--------------------------------------------------------------
Total 1,047 1,026 1,033 979
--------------------------------------------------------------
Number of customers:
Residential 4,429,896 4,381,563 4,295,838 4,196,010
Commercial 193,051 193,409 192,269 190,908
Industrial 25,642 26,530 26,957 27,133
Utility electric generation/wholesale 10 10 9 9
--------------------------------------------------------------
Total number of customers 4,648,599 4,601,512 4,515,073 4,414,060
--------------------------------------------------------------
Gas purchased (billion cubic feet):
Market gas: 140 149 202 219
30-day 168 226 161 87
Other --------------------------------------------------------------
308 375 363 306
Total market gas purchased 99 103 104 118
Affiliates 39 53 149 247
Other long-term supplies --------------------------------------------------------------
446 531 616 671
Total gas purchased --------------------------------------------------------------
Average cost of gas purchased excluding fixed costs $ 2.40 $ 2.59 $ 2.46 $ 2.39
(per thousand cubic feet) $ 2,663 $ 2,549 $ 2,386 $ 2,268
Weighted average rate base
Authorized rate of return on: 10.79% 10.75% 10.96% 10.93%
Rate base 13.00% 13.00% 13.00% 12.75%
Common equity 1,409 1,432 1,344 1,354
Degree days
1987 1986 1985
------------------------------------------------
CONSOLIDATED:
Operating revenues from continuing operations $ 3,385 $ 3,691 $ 4,955
------------------------------------------------
Income from continuing operations $ 148 $ 138 $ 105
Income (loss) from discontinued operations 101 (56) 82
------------------------------------------------
Net income (loss) 249 82 187
Dividends on preferred stock 6 6 6
------------------------------------------------
Net income (loss) applicable to common stock $ 243 $ 76 $ 181
------------------------------------------------
Net income (loss) per share of common stock:
Continuing operations $ 2.40 $ 2.27 $ 1.78
Discontinued operations 1.70 (.96) 1.47
------------------------------------------------
$ 4.10 $ 1.31 $ 3.25
------------------------------------------------
Cash dividends per share of common stock $ 3.48 $ 3.48 $ 3.36
Book value per share $ 27.05 $ 26.21 $ 27.70
Capital expenditures of continuing operations $ 328 $ 332 $ 372
Total assets $ 4,374 $ 4,584 $ 4,134
Capitalization:
Short-term debt $ 128 $ 469 $ 81
Long-term debt due within one year 72 16 48
Long-term debt 1,067 1,194 1,151
Long-term debt of ESOP 38 44 37
Obligations under capital leases 26 27 27
Preferred stocks of a subsidiary:
Redeemable 60 60 60
Nonredeemable 20 20 20
Preferred stock 110 110 110
Common stock 875 855 759
Retained earnings 771 734 838
Less deferred compensation relating to ESOP (38) (44) (37)
------------------------------------------------
Total capitalization $ 3,129 $ 3,485 $ 3,094
------------------------------------------------
Number of employees 27,928 26,571 26,550
SoCalGas:
Gas revenues:
Residential $ 1,496 $ 1,275 $ 1,596
Commercial/industrial 1,059 1,068 1,392
Utility electric generation 662 610 1,380
Wholesale 302 362 534
Exchange 18 19 14
------------------------------------------------
Gas revenues in rates 3,537 3,334 4,916
Regulatory balancing accounts and other (225) 274 (120)
------------------------------------------------
Total operating revenue $ 3,312 $ 3,608 $ 4,796
------------------------------------------------
Gas volumes delivered (billion cubic feet):
Residential 259 234 267
Commercial/industrial 269 223 223
Utility electric generation 309 225 318
Wholesale 159 124 130
Exchange 55 55 44
------------------------------------------------
Total 1,051 861 982
------------------------------------------------
Core n/a n/a n/a
Noncore n/a n/a n/a
------------------------------------------------
Total 1,051 861 982
------------------------------------------------
Gas volumes sold 759 767 938
Gas volumes transported or exchanged 292 94 44
------------------------------------------------
Total 1,051 861 982
------------------------------------------------
Number of customers:
Residential 4,086,365 3,969,671 3,878,861
Commercial 189,611 186,773 189,068
Industrial 27,227 27,942 29,047
Utility electric generation/wholesale 8 8 8
------------------------------------------------
Total number of customers 4,303,211 4,184,394 4,096,984
------------------------------------------------
Gas purchased (billion cubic feet):
Market gas: 271 242 118
30-day 48
Other ------------------------------------------------
319 242 118
Total market gas purchased 113 113 116
Affiliates 343 421 705
Other long-term supplies ------------------------------------------------
775 776 939
Total gas purchased ------------------------------------------------
Average cost of gas purchased excluding fixed costs $ 2.20 $ 2.52 $ 3.31
(per thousand cubic feet) $ 2,167 $ 2,092 $ 1,968
Weighted average rate base
Authorized rate of return on: 11.51% 12.74% 13.04%
Rate base 13.90% 14.60% 15.75%
Common equity 1,498 1,058 1,663
Degree days
QUARTERLY FINANCIAL DATA (UNAUDITED)
PAGE 56 PACIFIC ENTERPRISES
Three Months Ended
---------------------------------------------------
1995
---------------------------------------------------
(Dollars are in millions, except per-share amounts) Mar 31 Jun 30 Sep 30 Dec 31 Total
- -----------------------------------------------------------------------------------------------------------------------------
Operating revenues $ 618 $ 599 $ 528 $ 598 $ 2,343
Net income $ 45 $ 45 $ 47 $ 48 $ 185
Net income per share of common stock $ .51 $ .51 $ .55 $ .56 $ 2.12
Dividends declared per share of common stock $ .32 $ .68 $ $ .34 $ 1.34
Dividends paid per share of common stock $ .32 $ .34 $ .34 $ .34 $ 1.34
Weighted average number of shares of common stock
outstanding (in thousands) 82,128 82,230 82,320 82,382 82,265
- -----------------------------------------------------------------------------------------------------------------------------
- -----------------------------------------------------------------------------------------------------------------------------
Three Months Ended
---------------------------------------------------
1994
---------------------------------------------------
(Dollars are in millions, except per-share amounts) Mar 31 Jun 30 Sep 30 Dec 31 Total
- -----------------------------------------------------------------------------------------------------------------------------
Operating revenues $ 705 $ 651 $ 591 $ 717 $ 2,664
Net income $ 38 $ 42 $ 42 $ 50 $ 172
Net income per share of common stock $ .43 $ .47 $ .47 $ .58 $ 1.95
Dividends declared per share of common stock $ .30 $ .64 $ $ .32 $ 1.26
Dividends paid per share of common stock $ .30 $ .32 $ .32 $ .32 $ 1.26
Weighted average number of shares of common stock
outstanding (in thousands) 81,717 81,937 81,978 82,096 81,939
- -----------------------------------------------------------------------------------------------------------------------------
- -----------------------------------------------------------------------------------------------------------------------------
RANGE OF MARKET PRICES OF CAPITAL STOCK
1995
------------------------------------------------------------------------------------------------------
Three Months Ended Mar 31 Jun 30 Sep 30 Dec 31
- ------------------------------------------------------------------------------------------------------------------------------
Common Stock $24 7/8 - 21 $26 3/8 - 23 $25 3/8 - 22 3/8 $28 5/8 - 24 5/8
Preferred Stock:
$7.64 $93 - 81 $102 - 89
$4.75 $55 - 51 $67 1/4 - 55 5/8 $68 1/4 - 59 3/4 $71 1/4 - 65
$4.50 $53 3/8 - 47 1/2 $64 3/4 - 52 3/4 $63 51/64 - 59 1/2 $68 - 62
$4.40 $55 3/4 - 46 1/2 $64 - 51 5/8 $63 - 58 $67 5/8 - 60
$4.36 $53 57/64 - 47 $62 7/8 - 52 $62 29/64 - 54 1/2 $65 1/2 - 59
Remarketed(1)
- ------------------------------------------------------------------------------------------------------------------------------
- ------------------------------------------------------------------------------------------------------------------------------
(1)SEE NOTE 11 OF NOTES TO CONSOLIDATED FINANCIAL STATEMENTS.
1994
------------------------------------------------------------------------------------------------------
Three Months Ended Mar 31 Jun 30 Sep 30 Dec 31
- ------------------------------------------------------------------------------------------------------------------------------
Common Stock $24 1/2 - 20 $23 1/4 - 19 3/4 $22 - 19 1/4 $21 5/8 - 20
Preferred Stock:
$7.64 $101 5/8 - 92 $97 - 88 1/4 $94 3/8 - 87 1/8 $86 7/8 - 79 1/8
$4.75 $66 3/4 - 59 1/4 $60 - 52 $57 1/4 - 53 3/8 $54 - 50
$4.50 $64 3/8 - 55 1/4 $56 - 51 1/4 $55 - 51 1/4 $52 3/8 - 48 1/4
$4.40 $61 1/2 - 56 1/8 $58 7/8 - 52 $54 - 50 1/8 $51 1/2 - 47 7/8
$4.36 $62 5/8 - 53 1/2 $55 - 51 1/8 $53 3/8 - 49 1/2 $50 1/8 - 46 1/4
Remarketed(1)
- ------------------------------------------------------------------------------------------------------------------------------
- ------------------------------------------------------------------------------------------------------------------------------
(1)SEE NOTE 11 OF NOTES TO CONSOLIDATED FINANCIAL STATEMENTS.
MARKET PRICES FOR THE COMMON STOCK ARE AS REPORTED ON THE COMPOSITE TAPE FOR
STOCKS LISTED ON THE NEW YORK STOCK EXCHANGE. MARKET PRICES FOR THE PREFERRED
STOCK WERE OBTAINED FROM THE AMERICAN STOCK EXCHANGE. THE NUMBER OF SHAREHOLDERS
OF COMMON STOCK AT DECEMBER 31, 1995 IS 39,217.
- -------------------------------------------------------------------------------
DIRECTORS
PAGE 57 PACIFIC ENTERPRISES
[PHOTO OF DIRECTORS]
SEATED (LEFT) Willis B. Wood Jr., Richard D. Farman. STANDING (FROM LEFT)
Herbert L. Carter, Richard J. Stegemeier, Wilford D. Godbold Jr., Diana L.
Walker, Harold M. Messmer Jr., Ignacio E. Lozano Jr., Paul A. Miller, Hyla H.
Bertea
Hyla H. Bertea
COMMUNITY LEADER, CORONA DEL MAR, CALIFORNIA
Herbert L. Carter
EXECUTIVE VICE CHANCELLOR EMERITUS & TRUSTEE
PROFESSOR OF PUBLIC ADMINISTRATION,
CALIFORNIA STATE UNIVERSITY SYTEM,
LONG BEACH, CALIFORNIA
Richard D. Farman
PRESIDENT & CHIEF OPERATING OFFICER,
PACIFIC ENTERPRISES
Wilford D. Godbold, Jr.
PRESIDENT & CHIEF EXECUTIVE OFFICER,
ZERO CORPORATION,
LOS ANGELES
Ignacio E. Lozano, Jr.
EDITOR-IN-CHIEF, La Opinion, LOS ANGELES
Harold M. Messmer, Jr.
CHAIRMAN, PRESIDENT & CHIEF EXECUTIVE OFFICER,
ROBERT HALF INTERNATIONAL INC.
MENLO PARK, CALIFORNIA
Paul A. Miller
CHAIRMAN OF THE EXECUTIVE COMMITTEE,
PACIFIC ENTERPRISES
Richard J. Stegemeier,
RETIRED CHAIRMAN, UNOCAL CORPORATION,
BREA, CALIFORNIA
Diana L. Walker
PARTNER IN LAW FIRM OF O'MELVENY & MYERS,
LOS ANGELES
Willis B. Woods, Jr.
CHAIRMAN & CHIEF EXECUTIVE OFFICER,
PACIFIC ENTERPRISES
- -------------------------------------------------------------------------------
OFFICERS
PAGE 58 PACIFIC ENTERPRISES
PACIFIC ENTERPRISES
Willis B. Wood, Jr.
CHAIRMAN & CHIEF EXECUTIVE OFFICER
Richard D. Farman
PRESIDENT & CHIEF OPERATING OFFICER
Larry J. Dagley
SENIOR VICE PRESIDENT & CHIEF FINANCIAL OFFICER
Frederick E. John
SENIOR VICE PRESIDENT
John L. Estes
VICE PRESIDENT & CHIEF INFORMATION OFFICER
Leslie E. LoBaugh, Jr.
VICE PRESIDENT & GENERAL COUNSEL
Anne M. Miller
VICE PRESIDENT
G. Joyce Rowland
VICE PRESIDENT
Thomas S. Sayles
VICE PRESIDENT
Ralph Todaro
VICE PRESIDENT & CONTROLLER
Dennis V. Arriola
TREASURER
Thomas C. Sanger
CORPORATE SECRETARY
ENERGY MANAGEMENT SERVICES
Claude Harvey
PRESIDENT, PACIFIC ENERGY
Robert J. Salvaria
VICE PRESIDENT
NEW PRODUCT DEVELOPMENT
Anne M. Miller
VICE PRESIDENT
PACIFIC ENTERPRISES INTERNATIONAL
Christopher R. Sherman
PRESIDENT
John K. Peterson
VICE PRESIDENT
Raj P. Shah
VICE PRESIDENT
SOUTHERN CALIFORNIA GAS COMPANY
Warren I. Mitchell
PRESIDENT
Larry J. Dagley
SENIOR VICE PRESIDENT & CHIEF FINANCIAL OFFICER
Ralph Todaro
VICE PRESIDENT & CONTROLLER
Dennis V. Arriola
TREASURER
Thomas C. Sanger
CORPORATE SECRETARY
ENERGY DISTRIBUTION SERVICES
Debra L. Reed
SENIOR VICE PRESIDENT
Paul J. Cardenas
VICE PRESIDENT
John L. Estes
VICE PRESIDENT
Pamela J. Fair
VICE PRESIDENT
Richard M. Morrow
VICE PRESIDENT
Roy M. Rawlings
VICE PRESIDENT
ENERGY TRANSPORTATION SERVICES
Lee M. Stewart
SENIOR VICE PRESIDENT
Eric B. Nelson
VICE PRESIDENT
Anne S. Smith
VICE PRESIDENT
George E. Strang
VICE PRESIDENT
CORPORATE INFORMATION
SHAREHOLDER INFORMATION
Stock Transfer Agent and Registrar
Chemical Mellon Shareholder Services
Washington Bridge Station
P.O. Box 590
Ridgefield Park, NJ 07660
1-800-715-4473
STOCK EXCHANGE LISTING
Common Stock:
New York Stock Exchange
Pacific Stock Exchange
Ticker Symbol: PET
Preferred Stock:
American Stock Exchange
Pacific Stock Exchange
DIVIDEND REINVESTMENT AND STOCK
PURCHASE PLAN
Shareholders are entitled to participate in the Company's Dividend Reinvestment
and Stock Purchase Plan, under which cash dividends and optional cash payments
are invested in shares of Pacific Enterprises common stock.
ADDITIONAL INFORMATION
Shareholders may request additional information about Pacific Enterprises by
calling Clem Teng, Director of Investor Relations, at 213-244-3966, or the
Shareholder Services Department at 1-800-722-5483. Pacific Enterprises also can
be found on the internet at http://www.pacent.com
ANNUAL MEETING
Written notice of business, including nominations for directors, to be brought
by shareholders before the Company's 1997 Annual Meeting, must be received by
the secretary of the Company on or before March 10, 1997. The notice must
contain the information specified in the Company's bylaws.
The Board of Directors has a Nominating Committee which considers and makes
recommendations regarding the nominations of directors and the size and
composition of the Board of Directors. The committee will consider shareholders'
suggestions for nominees for director. Suggestions may be submitted to the
secretary of the Company, P.O. Box 60043, Los Angeles, California 90060-0043.
Biographical information concerning the proposed nominee also should be included
to assist the committee in its deliberations.
CREDIT RATINGS
Duff &
S&P Phelps Moody's
- -------------------------------------------------------------
Pacific Enterprises
Preferred stock A+ BBB+ baa2
SoCalGas
Secured debt AA- A+ A2
Unsecured debt A+ A A3
Commercial paper A1+ D1+ P1
Preferred stock AA- A a2
- -------------------------------------------------------------
PACIFIC ENTERPRISES
555 West 5th Street
Suite 2900
Los Angeles, California 00013-1011
212-895-5000
EXHIBIT 21.01
LIST OF SUBSIDIARIES
OF PACIFIC ENTERPRISES
Burney Mountain Power
Central Plants, Inc.
Coalition Undertaking Remedial Efforts, Inc.
EcoTrans OEM Corporation
Ensource
FTM Sports Corporation
Landfill Control Technologies
Mammoth Geothermal Company
Mammoth Power Company
Mt. Lassen Power
Pacific Bio-Energy Company
Pacific Enerchange
Pacific Energy
Pacific Energy Resources Incorporated
Pacific Enterprises
Pacific Enterprises ABC Corporation
Pacific Enterprises Commercial Loans, Inc.
Pacific Enterprises International
Pacific Enterprises International Argentina I
Pacific Enterprises Leasing Company
Pacific Enterprises LNG Company
Pacific Enterprises Oil Company
Pacific Enterprises Oil Company (Canada)
Pacific Enterprises Oil Company (USA)
Pacific Enterprises Oil Company (Western)
Pacific Enterprises Minerals Company
Pacific Gas Gathering Company
Pacific Geothermal Company
Pacific Hydropower Company
Pacific Interstate Company
Pacific Interstate Mojave Company
Pacific Interstate Offshore Company
Pacific Interstate Transmission Company
Pacific Interstate Transmission Company (Arctic)
Pacific Library Tower
Pacific Lighting Corporation
Pacific Lighting Gas Development Company
Pacific Lighting Land Company
Pacific Lighting Real Estate Group
Pacific Offshore Pipeline Company
Pacific Oroville Power, Inc.
Pacific Penobscot Power Company
Pacific Recovery Corporation
Pacific Synthetic Fuel Company
Pacific Western Resources Company
Pacific Wood Fuels Company
Pacific Wood Power
Pay'n Save Drug Stores, Incorporated
Penstock Power Company
Presley-Home Mac Finance Co., Inc.
Presley RAC Finance Co., Inc.
Southern California Gas Company
Southern California Gas Tower
8309 Tujunga Avenue Corp.
EXHIBIT 23.01
INDEPENDENT AUDITORS' CONSENT
We consent to the incorporation by reference in Registration Statement Nos.
2-96782, 33-26357, 2-66833, 2-96781, 33-21908 and 33-54055 of Pacific
Enterprises on Forms S-8 and Registration Statement Nos. 33-24830 and
33-44338 of Pacific Enterprises on Forms S-3 of our reports dated January 31,
1996, appearing in and incorporated by reference in this Annual Report on
Form 10-K of Pacific Enterprises for the year ended December 31, 1995.
DELOITTE & TOUCHE LLP
Los Angeles, California
March 21, 1996
UT
1,000,000
12-MOS
DEC-31-1995
DEC-31-1995
PER-BOOK
3,282
53
1,170
645
109
5,259
1,111
0
236
1,295
0
188
1,241
234
0
0
100
0
0
0
2,201
5,259
2,343
129
0
1,955
422
34
0
108
185
10
175
111
0
698
2.12
2.12
